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Home My WebLink About162-037Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 2/16/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20250216 Well API #PTD #Log Date Log Company Log Type AOGCC Eset # BRU 232-04 50283100230000 132037 1/18/2025 AK E-LINE Perf CLU 08 50133205340000 204005 2/13/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 1/2/2025 YELLOWJACKET SCBL CLU 10RD2 50133205530200 224135 12/13/2024 YELLOWJACKET SCBL CLU 7 50133205310000 203191 1/25/2025 YELLOWJACKET SCBL IRU 44-36 50283200890000 193022 1/21/2025 AK E-LINE Plug/Perf KALOTSA 10 50133207320000 224147 2/11/2025 YELLOWJACKET SCBL KALOTSA 9 50133207310000 224145 1/26/2025 YELLOWJACKET SCBL KBU 22-06Y 50133206500000 215044 1/11/2025 YELLOWJACKET SCBL KU 13-06A 50133207160000 223112 1/12/2025 YELLOWJACKET SCBL MRU M-25 50733203910000 187086 1/15/2024 AK E-LINE PPROF NCIU A-21 50883201990000 224086 1/6/2024 AK E-LINE Plug/Perf PBU 06-05A 50029202980100 224115 1/14/2025 HALLIBURTON RBT PBU 09-35B 50029213140200 224122 2/3/2025 HALLIBURTON RBT PBU B-12B 50029203320200 224133 1/20/2025 HALLIBURTON RBT PBU D-12 50029204430000 180015 12/19/2024 BAKER SPN PBU F-08B 50029201350200 212040 1/27/2025 HALLIBURTON RBT PBU NK-41A 50029227780100 197158 12/18/2024 YELLOWJACKET CBL PBU S-100A 50029229620100 224083 1/5/2025 HALLIBURTON RBT Revision Explanation: Annotations added to processed log. Please include current contact information if different from above. 162-037 T40080 T40081 T40082 T40082 T40083 T40084 T40085 T40086 T40087 T40088 T40089 T40090 T40091 T40092 T40093 T40094 T40095 T40096 T40097 BRU 232-04 50283100230000 132037717 1/18/2025 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.02.18 13:06:47 -09'00' 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Development Exploratory 3. Address:Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5,300 feet 3168; 4017 feet true vertical 5,300 feet N/A feet Effective Depth measured 3,168 feet 2793 & 3748 feet true vertical 3,168 feet 2793 & 3748 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.3# / J-55 3,747' MD 3,747' TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.7# / N-80 4,573' MD 4,573' TVD Bkr SC 1L GP Pkr; 2,793' MD/TVD Packers and SSSV (type, measured and true vertical depth)Bkr DB Perm Pkr; N/A 3,748' MD/TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date:Contact Name: Contact Email: Authorized Title:Contact Phone: Chad Helgeson, Operations Engineer 324-673 Sr Pet Eng:Sr Pet Geo:Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 40 Size 43' 0 400 0 700 9 measured TVD 10-3/4" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 162-037 50-283-10023-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA-029656 Beluga River / Sterling-Beluga Gas Beluga River Unit (BRU) 232-04 Plugs Junk measured Length Production Liner 2,226' 4,661' Casing Structural 2,240' 4,675' 2,240' 4,675' 43'Conductor Surface Intermediate 36" 16" 29' 288' 3,220psi 3,830psi 2,630psi 5,860psi 6,340psi 302'302' Burst Collapse 1,020psi p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:17 pm, Feb 03, 2025 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2025.02.03 10:40:05 - 09'00' Noel Nocas (4361) DSR-2/18/25 RBDMS JSB 021825 BJM 3/12/25 Perforate SFD 2/27/2025 Well Name: BRU 232-04 API #:50-283-10023-00-00 Field:Beluga River Start Date:1/8/2025 Permit #:162-037 Sundry #:324-673 End Date:1/19/2025 1/8/2025 1/9/2025 1/10/2025 1/12/2025 1/16/2025 1/19/2025 Daily Operations: PJSM, Travel to location, Pick up lube & tools, Pressure test 250/2000-good, Run in hole to tag @ 3162', Correlate, Perf the ST X3 Lower 3145-3150, Pull out of the well, Attempt to flow well, Pick up run #2, Run in hole, Tag @ 3030', Pull out of hole fill too high to perf, Rig down & release to Ivan River Activity Report WOC, PJSM, Crew travel to location, Pick up lube & tool string 2.62" GR, Pressure test 250/2000-good, Run in hole, Tag @ 3167', Pull out of hole, Rig down & move to H-pad PJSM, Spot in & rig up vac truck, Load well with 27 bbls total, Attempt to pressure up, Slow bleed off, Shut in & secure well for the night. PJSM, Crew Mob from IRU to well, Spot in & rig up, Pick up lube & tool string (GPT & Guage Ring 2.8"), Stab onto well, Pressure test 250/2000 psi-good, Run in hole to tag @ 2765', Pull out of the hole, Pick up run #2, GR 2.62" w/ GPT, Run in hole, Fluid @ 1565', Run to 3380', Pull out of hole logging, Rig down & secure well for the night. PJSM, Crew travel to location, Start & warm equipment, Pick up lube & tool string (2.5" CIBP & CCL), Pressure test 250/2000-good, Run in hole with run #1, Correlate, Set plug @ 3179', Tag & log off-good, Pick up run #2 (hole punch), Run in hole & tag plug, Perf @ 3174'-3177', Pull out of hole, Pick up Run #3 (hole punch), Run in hole, Perf @ 3172.5'-3175.5', Pull out of the hole, Pick up jet cutter, Run in hole with run #4, Correlate, Cut @ 3174', Pull out of hole, Pick up & make up run #5 (Bailer 20'), Run in hole & tag @ 3175', Bail 2.7 gal cmt slurry, EST TOC @ 3168', Pull out of hole, Secure well & rig down for the night. Determined well clear of obstruction to 2753'KB- Swabbed well fluid from 1480' to 1760' with noted influx throughout swabbing operations PJSM, Crew travel to H-pad, Mob equipment to B-pad, Spot in & rig up, Pick up lube & tool string on .16 wire, Pressure test 500/2000- good, Make up 2.8" GR, Run in the hole to tag @ 2753', Pull out of hole, Make up 3.5" swab tools, fluid top @ 1480', Make 10 runs recover 16 bbls, Swabbed fluid to 1760', Secure well & rig down. Page 1 of 1 _____________________________________________________________________________________ Updated by CAH 01-31-25 SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = 3,752’ PBTVD = 3,752’ Max Angle = 1 deg @ 1,590’ TOC @ 2960’ 10-3/4” P1 3 4 5/6 7 7A 7B 8 9 10 12 13 14 15 A A B B C D D E F F .25” control line 2 11 Could not pass 4038’ (2019 CTU FCO) Punch 3172- 3177 CASING DETAIL Size Type WT Grade Conn ID Btm 36''Conductor 43' 16''Surface 75#J-55 8rd 15.124''302' 10-3/4"Intermediate 55.5#N-80 S8R 9.76''1,831' 10-3/4"Intermediate 51#N-80 S8R 9.85''2,240' 7''Production Casing 23#N-80 Butt 6.366''4,675' TUBING DETAILS 3.5"Production String 9.3#J-55 EUE 8rd, AB 2.992''3,747’ 2-3/8"Production Tailpipe 4.7#N-80 EUE 8rd 1.995''4,573' JEWELRY DETAIL ID.Depth MD (ft.)ID (in.)Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer / SA 6 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 7 2,817 3 Shear out Safety joint, 57k shear 7A 3,174’Tubing cut w/Tubing punch 3172-3177’ big hole charges (1/9/25) 7B 3,179’ NA CIBP (set 6” below collar @ ~3220’) cement dumped on plug - TOC 3,168’ (1/9/25) 8 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 9 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 10 3,747 2.406 Baker 5-22 Snap Latch SA / Baker 'DB' Packer perm w MOE 11 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 12 3,791 1.875 Otis 'X' Nipple 13 4,017 CIBP 7/4/2024 14 4,571 1.79 Otis 'XN' Nipple 15 4,572 Baker Wireline Entry Guide Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 4,629 -Float Collar PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status Pool Top per CO 802a – 2950’ MD / 2949’ TVD X3 3,145’3,150’3,145’3,150’5 6 1/19/25 Open 3,181’3,206’3,181’3,206’25’12 12/13/1988 Grvl Pck (Isolated) A 3,231'3,264'3,231'3,264'33'12 12/13/1988 Grvl Pck (Isolated) A 3,300'3,324'3,300'3,324'24’'12 12/13/1988 Grvl Pck (Isolated) 3,350’3,357’3,350’3,357’7’12 12/13/1988 Grvl Pck (Isolated) B 3,404'3,416’'3,404'3,416'12’12 12/13/1988 Grvl Pck (Isolated) B 3,423’3,453’3,423’3,453’30’12 12/13/1988 Grvl Pck (Isolated) B 3,471’3,484’3,471’3,484’13’12 12/13/1988 Grvl Pck (Isolated) B 3,508’3,513’3,508’3,513’5’12 12/13/1988 Grvl Pck (Isolated) C 3,562'3,584’3,562'3,584’22’12 12/13/1988 Grvl Pck (Isolated) C 3,599’3,625’3,599’3,625’26’12 12/13/1988 Grvl Pck (Isolated) C 3,638’3,649’3,638’3,649’11’12 12/13/1988 Grvl Pck (Isolated) C 3,662’3,666’3,662’3,666’4’12 12/13/1988 Grvl Pck (Isolated) D 3,696'3,709'3,696'3,709'13’12 12/13/1988 Grvl Pck (Isolated) D 3,720’3,734’3,720’3,734’14’12 12/13/1988 Grvl Pck (Isolated) D3 3,807’3,817’3,807’3,817’10’4 7/26/2024 Isolated D4 3,830’3,838’3,830’3,838’8’4 7/26/2024 Isolated D5 3,863’3,878’3,863’3,878’15’4 7/26/2024 Isolated D6 3,890’3,902’3,890’3,902’12’4 7/26/2024 Isolated E 4,048'4,058'4,048'4,058'10'16 12/10/1988 Isolated E 4,220'4,227'4,220'4,227'7'16 12/10/1988 Isolated F 4,443'4,450'4,443'4,450'7'16 1/29/63 & 88 Isolated F 4,489'4,503'4,489'4,503'14 16 1/29/63 & 88 Isolated F 4,538'4,545'4,538'4,545'7 16 1/28/63 & 88 Isolated Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 1/28/2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240128 Well API #PTD #Log Date Log Company Log Type AOGCC ESet # BCU 14B 50133205390200 222057 10/21/2024 YELLOWJACKET GPT-PLUG-PERF BRU 232-04 50283100230000 162037 1/8/2025 AK E-LINE TubingPlugCut BRU 241-34S 50283201980000 224077 1/11/2025 AK E-LINE Perf END 2-16 50029218850000 188134 10/6/2024 YELLOWJACKET PERF MPU H-08B 50029228080200 201047 1/9/2025 READ CaliperSurvey MRU M-25 50733203910000 187086 1/2/2025 AK E-LINE Perf PEAR 11 50133207120000 223032 10/2/2024 YELLOWJACKET PLUG-PERF Please include current contact information if different from above. T40025 T40026 T40027 T40028 T40032 T40033 T40035 BRU 232-04 50283100230000 162037 1/8/2025 AK E-LINE TubingPlugCut Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.01.29 10:55:36 -09'00' 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ________ 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5,300'N/A Casing Collapse Structural Conductor Surface 1,020psi Intermediate 3,220psi Production 3,830psi Liner Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng chelgeson@hilcorp.com 907-777-8405 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 3-1/2" PRESENT WELL CONDITION SUMMARY Chad Helgeson, Operations Engineer AOGCC USE ONLY Tubing Grade: 9.3# / J-55 Tubing MD (ft): 3,747'Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 029656 162-037 50-283-10023-00-00 Hilcorp Alaska, LLC Proposed Pools: 4.7# / N-80 TVD Burst 4,573' 6,340psi 302' Size 29' 10-3/4"2,226' 288' MD See Attached Schematic 5,860psi 2,630psi 43' 2,240' 43' 302' November 15, 2024 2-3/8" 4,675' Perforation Depth MD (ft): 2,240' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 232-04CO 802A Same 4,675'7" ~1044psi 4,661' 4,017' Length Bkr SC 1L GP Pkr; Bkr DB Perm Pkr; N/A 2,793' MD/TVD; 3,747' MD/TVD; N/A, N/A 5,300' 4,017' 4,017' Beluga River Sterling-Beluga Gas 36" 16" See Attached Schematic __ No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 3:24 pm, Nov 01, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.11.01 12:23:04 - 08'00' Noel Nocas (4361) DSR-11/6/24A.Dewhurst 04DEC24 324-673 BJM 12/23/24 10-404 MEUIRUMOF Gregory C. Wilson Digitally signed by Gregory C. Wilson Date: 2024.12.24 12:01:12 -09'00'12/24/24 RBDMS JSB 123024 Well Prognosis Well Name:BRU 232-04 API Number:50-283-10023-00 Current Status:SI Gas Producer Permit to Drill Number:162-037 First Call Engineer:Chad Helgeson (907) 777-8405 (907) 229-4824 (C) Second Call Engineer:Scott Warner (907) 830-8863 Maximum Expected BHP:~ 1,361 psi @ 3,166’ TVD (Calc’d W/ .43 psi/ft gradient) Max. Predicted Surface Pressure:~ 1,044 psi (BHP minus 0.1 psi/ft. gas grad.) Applicable Frac Gradient: NA, Single Perf interval, can’t frac itself Shallowest Potential Perf TVD:2950’ MD: 2949‘ TVD (top of pool) Top of Pools per CO 802a:Sterling-Beluga Gas Pool: 2,950’ MD, 2949’ TVD Well Status SI Gas Producer, last production 2018 Brief Well Summary Originally drilled in early 1963 and completed in the Beluga F, G and H with a single string and a heater string. A workover in 1988 added the Sterling and Beluga A through D intervals with a gravel pack over the newly added sands. BRU 232-04 is a single 3-1/2” production string to 2,791’ w/ gravel pack screen from 3,162’ to 3,747’. The well was flowing 1.8-2 MMscfd and would not come back on after a shutdown in late December of 2017. In 2020 a CIBP was set below the lower straddle to isolate the E & F sands, followed by an unsuccessful attempt to swab the well online. In August of 2024, coil cleaned out well and Beluga Perfs were added in tubing tail. They were unsuccessful and no production came from these perfs. The purpose of this work/ sundry is to attempt to set/create isolation in the gravel pack and perforate stray sterling sands above existing perforations. All existing & proposed sands lie in the Sterling-Beluga Gas Pool. Notes Regarding Wellbore Condition x Vertical wellbore x Gravel pack eval log (5/6/18) indicates top of silicone (gravel pack) @ ~3,060’ x Gravel pack was installed in 1988 with 60/40 mesh x Chemical inj mandrel @ 2718’ x X Nipple @ 2758’ Procedure 1. MIRU E-line, PT lubricator to 2,000 psi 2. PU 3-1/2” CIBP and set @ 3220’ (6” below the collar to be in base pipe – not in screen) 3. PU pipe cutter and cut with cutter to cut through entire screen @ ~3219’ 4. PU large bore guns, shallow penetration and big hole, perf screens from ~3209-3219’ 5. PU 20ft dump bailer and load 3.6 gal of thin cement (~12-13 ppg), RIH and dump cement on plug 6. Wait on cement to cure 7. RIH and tag cement a) (if cement is 10ft above plug) repeat cut and tubing punches and try again b) (if cement is below ~3212) fill well with 8.4 ppg water (no more than 28 bbls) i. RIH with another 2 gal of cement and dump on cement plug ii. Wait on cement iii. Pressure up well to 200 psi to see if cement plug holds iv. Repeat steps 3-5 until cement gets through screen and into gravel pack or tubing tag gets to 3170’ CIBP to be set at 3179' and cut screen at 3177' MD per attached email from Chad Helgeson 12/3/24. -bjm Well Prognosis 8. RD Eline/RU SL 9. Swab well down to 2758’ x-nipple location (if possible across chem inj mandrel) 10. Perforate the following sands within the below gross interval: Sand MD Top MD Base TVD Top TVD Base Date Top Sterling/Beluga Gas Pool 2,950’ 2949’ Sterling X3 Upper 3130’ 3157’ 3130 3156’ TBD Sterling X3 Lower 3162 3167 3161 3166 TBD 11. Return well to production and complete SVS Testing per 20AAC 25.265. Attachments: 1. Actual Schematic 2. Proposed Schematic _____________________________________________________________________________________ Updated by DMA 08-09-24 SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = 3,752’ PBTVD = 3,752’ Max Angle = 1 deg @ 1,590’ TOC @ 2960’ 10-3/4” P1 3 4 5/6 7 8 9 10 12 13 14 15 A A B B C D D E F F .25” control line2 11 Could not pass 4038’ (2019 CTU FCO) CASING DETAIL Size Type WT Grade Conn ID Btm 36''Conductor 43' 16''Surface 75#J-55 8rd 15.124''302' 10-3/4"Intermediate 55.5#N-80 S8R 9.76''1,831' 10-3/4"Intermediate 51#N-80 S8R 9.85''2,240' 7''Production Casing 23#N-80 Butt 6.366''4,675' TUBING DETAILS 3.5"Production String 9.3#J-55 EUE 8rd, AB 2.992''3,747’ 2-3/8"Production Tailpipe 4.7#N-80 EUE 8rd 1.995''4,573' JEWELRY DETAIL Production Tubing ID.Depth MD (ft.)ID (in.)Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer / SA 6 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 7 2,817 3 Shear out Safety joint, 57k shear 8 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 9 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 10 3,747 2.406 Baker 5-22 Snap Latch SA / Baker 'DB' Packer perm w MOE 11 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 12 3,791 1.875 Otis 'X' Nipple 13 4,017 CIBP 7/4/2024 14 4,571 1.79 Otis 'XN' Nipple 15 4,572 Baker Wireline Entry Guide Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 4,629 -Float Collar PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status A 3,231'3,264'3,231'3,264'33'12 12/13/1988 Grvl Pck A 3,300'3,357'3,300'3,357'31'12 12/13/1988 Grvl Pck B 3,404'3,513'3,404'3,513'60'12 12/13/1988 Grvl Pck C 3,562'3,666'3,562'3,666'63'12 12/13/1988 Grvl Pck D 3,696'3,734'3,696'3,734'23'12 12/13/1988 Grvl Pck D3 3,807’3,817’3,807’3,817’10’4 7/26/2024 Open D4 3,830’3,838’3,830’3,838’8’4 7/26/2024 Open D5 3,863’3,878’3,863’3,878’15’4 7/26/2024 Open D6 3,890’3,902’3,890’3,902’12’4 7/26/2024 Open E 4,048' 4,058' 4,048' 4,058'10'16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227'7'16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450'7'16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/96 Note: There are additional existing perfs not shown on this diagram. See attached email from Andy Dewhurst 12/2/24. Shallowest existing perfs are 3181-3206' MD, others detailed in the updated proposed diagram attached. -bjm _____________________________________________________________________________________ Updated by CAH 10-30-24 SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = 3,752’ PBTVD = 3,752’ Max Angle = 1 deg @ 1,590’ TOC @ 2960’ 10-3/4” P1 3 4 5/6 7 7A 7B 8 9 10 12 13 14 15 A A B B C D D E F F .25” control line2 11 Could not pass 4038’ (2019 CTU FCO) CASING DETAIL Size Type WT Grade Conn ID Btm 36'' Conductor 43' 16'' Surface 75# J-55 8rd 15.124'' 302' 10-3/4" Intermediate 55.5# N-80 S8R 9.76'' 1,831' 10-3/4" Intermediate 51# N-80 S8R 9.85'' 2,240' 7'' Production Casing 23# N-80 Butt 6.366'' 4,675' TUBING DETAILS 3.5" Production String 9.3# J-55 EUE 8rd, AB 2.992'' 3,747’ 2-3/8" Production Tailpipe 4.7# N-80 EUE 8rd 1.995'' 4,573' JEWELRY DETAIL Production Tubing ID. Depth MD (ft.) ID (in.) Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer / SA 6 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 7 2,817 3 Shear out Safety joint, 57k shear 7A ±3,219’ Tubing cut (through screens) Tubing punch ~3209-3219’ big hole charges 7B ±3,220’ NA CIBP (set 6” below collar @ ~3220’) cement dumped on plug 8 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 9 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 10 3,747 2.406 Baker 5-22 Snap Latch SA / Baker 'DB' Packer perm w MOE 11 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 12 3,791 1.875 Otis 'X' Nipple 13 4,017 CIBP 7/4/2024 14 4,571 1.79 Otis 'XN' Nipple 15 4,572 Baker Wireline Entry Guide Plugs/Other ID. Depth MD (ft.) ID (in.) Description NA P1 4,629 - Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status Pool Top per CO 802a – 2950’ MD / 2949’ TVD X3 ±3,130’ ±3,157’ ±3,130’ ±3,156’ ±27 6 TBD Proposed X3 ±3,162’ ±3,167’ ±3,161’ ±3,166’ ±5 6 TBD Proposed A 3,231' 3,264' 3,231' 3,264' 33' 12 12/13/1988 Grvl Pck (Isolated) A 3,300' 3,357' 3,300' 3,357' 31' 12 12/13/1988 Grvl Pck (Isolated) B 3,404' 3,513' 3,404' 3,513' 60' 12 12/13/1988 Grvl Pck (Isolated) C 3,562' 3,666' 3,562' 3,666' 63' 12 12/13/1988 Grvl Pck (Isolated) D 3,696' 3,734' 3,696' 3,734' 23' 12 12/13/1988 Grvl Pck (Isolated) D3 3,807’ 3,817’ 3,807’ 3,817’ 10’ 4 7/26/2024 Isolated D4 3,830’ 3,838’ 3,830’ 3,838’ 8’ 4 7/26/2024 Isolated D5 3,863’ 3,878’ 3,863’ 3,878’ 15’ 4 7/26/2024 Isolated D6 3,890’ 3,902’ 3,890’ 3,902’ 12’ 4 7/26/2024 Isolated E 4,048' 4,058' 4,048' 4,058' 10' 16 12/10/1988 Isolated E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Isolated F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Isolated F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Isolated F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Isolated Superseded by updated proposed schematic. -A.Dewhurst 04DEC24 _____________________________________________________________________________________ Updated by CAH 12-3-24 PROPOSED Rev 1 Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = 3,752’ PBTVD = 3,752’ Max Angle = 1 deg @ 1,590’ TOC @ 2960’ 10-3/4” P1 3 4 5/6 7 7A 7B 8 9 10 12 13 14 15 A A B B C D D E F F .25” control line2 11 Could not pass 4038’ (2019 CTU FCO) CASING DETAIL Size Type WT Grade Conn ID Btm 36''Conductor 43' 16''Surface 75#J-55 8rd 15.124''302' 10-3/4"Intermediate 55.5#N-80 S8R 9.76''1,831' 10-3/4"Intermediate 51#N-80 S8R 9.85''2,240' 7''Production Casing 23#N-80 Butt 6.366''4,675' TUBING DETAILS 3.5"Production String 9.3#J-55 EUE 8rd, AB 2.992''3,747’ 2-3/8"Production Tailpipe 4.7#N-80 EUE 8rd 1.995''4,573' JEWELRY DETAIL Production Tubing ID.Depth MD (ft.)ID (in.)Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer / SA 6 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 7 2,817 3 Shear out Safety joint, 57k shear 7A ±3,177’Tubing cut (through screens) Tubing punch ~3174-3178’ big hole charges 7B ±3,179’NA CIBP (set 6” below collar @ ~3220’) cement dumped on plug 8 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 9 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 10 3,747 2.406 Baker 5-22 Snap Latch SA / Baker 'DB' Packer perm w MOE 11 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 12 3,791 1.875 Otis 'X' Nipple 13 4,017 CIBP 7/4/2024 14 4,571 1.79 Otis 'XN' Nipple 15 4,572 Baker Wireline Entry Guide Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 4,629 -Float Collar PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status Pool Top per CO 802a – 2950’ MD / 2949’ TVD X3 ±3,130’±3,157’±3,130’±3,156’±27 6 TBD Proposed X3 ±3,162’±3,167’±3,161’±3,166’±5 6 TBD Proposed 3,181’3,206’3,181’3,206’25’12 12/13/1988 Grvl Pck (Isolated) A 3,231'3,264'3,231'3,264'33'12 12/13/1988 Grvl Pck (Isolated) A 3,300'3,324'3,300'3,324'24’'12 12/13/1988 Grvl Pck (Isolated) 3,350’3,357’3,350’3,357’7’12 12/13/1988 Grvl Pck (Isolated) B 3,404'3,416’'3,404'3,416'12’12 12/13/1988 Grvl Pck (Isolated) B 3,423’3,453’3,423’3,453’30’12 12/13/1988 Grvl Pck (Isolated) B 3,471’3,484’3,471’3,484’13’12 12/13/1988 Grvl Pck (Isolated) B 3,508’3,513’3,508’3,513’5’12 12/13/1988 Grvl Pck (Isolated) C 3,562'3,584’3,562'3,584’22’12 12/13/1988 Grvl Pck (Isolated) C 3,599’3,625’3,599’3,625’26’12 12/13/1988 Grvl Pck (Isolated) C 3,638’3,649’3,638’3,649’11’12 12/13/1988 Grvl Pck (Isolated) C 3,662’3,666’3,662’3,666’4’12 12/13/1988 Grvl Pck (Isolated) D 3,696'3,709'3,696'3,709'13’12 12/13/1988 Grvl Pck (Isolated) D 3,720’3,734’3,720’3,734’14’12 12/13/1988 Grvl Pck (Isolated) D3 3,807’3,817’3,807’3,817’10’4 7/26/2024 Isolated D4 3,830’3,838’3,830’3,838’8’4 7/26/2024 Isolated D5 3,863’3,878’3,863’3,878’15’4 7/26/2024 Isolated D6 3,890’3,902’3,890’3,902’12’4 7/26/2024 Isolated E 4,048'4,058'4,048'4,058'10'16 12/10/1988 Isolated E 4,220'4,227'4,220'4,227'7'16 12/10/1988 Isolated F 4,443'4,450'4,443'4,450'7'16 1/29/63 & 88 Isolated F 4,489'4,503'4,489'4,503'14 16 1/29/63 & 88 Isolated F 4,538'4,545'4,538'4,545'7 16 1/28/63 & 88 Isolated 1 Dewhurst, Andrew D (OGC) From:Chad Helgeson <chelgeson@hilcorp.com> Sent:Tuesday, 3 December, 2024 19:45 To:Dewhurst, Andrew D (OGC) Cc:McLellan, Bryan J (OGC); Davies, Stephen F (OGC); Guhl, Meredith D (OGC); Donna Ambruz Subject:RE: [EXTERNAL] BRU 323-04 Sundry (324-673): Question Attachments:BRU 232-04 PROPOSED Rev 12-3-24.pdf Follow Up Flag:Follow up Flag Status:Flagged Andy, Thanks for catching that for us. Our records also indicate that the well is perforated as you have listed in the historic well ﬁles, but was not correct on our well schematic. I have updated the current schematic showing the top perf interval that was missing. The other highlighted perfs were included in the range of perf intervals listed on the schematic, but they are all updated on the proposed rev schematic with exact perf depths. The upper zone does change our program a little from a depth where we plan to try and place the plug, but doesn’t change the procedure for the attempt to get some isolation of the perfs in the gravel pack/screen completion. The new proposed schematic shows the new plug depth at 3179’ and the punches and tubing cut shallower at 3177’. We will also use less cement to push away initially, and try to get the isolation. Some additional info about this project: The current perfs are watered out, we believe the new zones will have gas in them and be at high enough pressure (original) to ﬂow the water from lower zones with it, however the zone is not present on other nearby wells so it is not expected to be a large volumes of gas, so the plug is an attempt to extend the life of this zone when it does deplete and may not have enough energy to unload the water. If the plug does not get complete isolation, we will continue with our plans for perforating the new sands, as it is not a plug that we expect is required to have some success. The expected volumes of gas in this zone are not expected to be economic for a RWO or some sort of coil isolation with the gravel pack. Please let me know if you need anything additional on this project or procedure. Chad From: Dewhurst, Andrew D (OGC) <andrew.dewhurst@alaska.gov> Sent: Monday, December 2, 2024 1:10 PM To: Chad Helgeson <chelgeson@hilcorp.com> Cc: McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov>; Davies, Stephen F (OGC) <steve.davies@alaska.gov>; Guhl, Meredith D (OGC) <meredith.guhl@alaska.gov> Subject: [EXTERNAL] BRU 323-04 Sundry (324-673): Question CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. CAUTION: External sender. DO NOT open links or attachments from UNKNOWN senders. 2 Chad, I am reviewing this sundry and have a quesƟon: x In the historical well ﬁle, I have found reference to addiƟonal perforated intervals to those listed on the included schemaƟc. I’m copying a screenshot of one of those with my highlights. Would you please inves Ɵgate this and let us know the history/status of these intervals? Thanks, Andy Andrew Dewhurst Senior Petroleum Geologist Alaska Oil and Gas ConservaƟon Commission 333 W. 7th Ave, Anchorage, AK 99501 andrew.dewhurst@alaska.gov Direct: (907) 793-1254 The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. 3 While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. 1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: N2 Development Exploratory 3. Address: Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5,300 feet 4,017 feet true vertical 5,300 feet N/A feet Effective Depth measured 4,017 feet 2793 & 3748 feet true vertical 4,017 feet 2793 & 3748 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet 3-1/2" 9.3# / J-55 3,747' MD 3,747' TVD Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.7# / N-80 4,573' MD 4,573' TVD Bkr SC 1L GP Pkr; 2,793' MD/TVD Packers and SSSV (type, measured and true vertical depth) Bkr DB Perm Pkr; N/A 3,748' MD/TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 3,220psi 3,830psi 2,630psi 5,860psi 6,340psi 302' 302' Burst Collapse 1,020psi Production Liner 2,226' 4,661' Casing Structural 2,240' 4,675' 2,240' 4,675' 43'Conductor Surface Intermediate 36" 16" 29' 288' measured TVD 10-3/4" 7" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 162-037 50-283-10023-00-00 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Hilcorp Alaska, LLC N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: FEDA-029656 Beluga River / Sterling-Beluga Gas Beluga River Unit (BRU) 232-04 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf MD 40 Size 43' 0 400 0 4500 80 Chad Helgeson, Operations Engineer 324-353 Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 0 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Noel Nocas, Operations Manager 907-564-5278 N/A chelgeson@hilcorp.com 907-777-8405 p k ft t Fra O s 6. A G L PG , Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 3:54 pm, Aug 23, 2024 Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.08.23 15:11:07 - 08'00' Noel Nocas (4361) Page 1/1 Well Name: BRU 232-04 Report Printed: 8/7/2024www.peloton.com Alaska Weekly Report - Operations Jobs Actual Start Date:7/3/2024 End Date: Report Number 1 Report Start Date 7/3/2024 Report End Date 7/4/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up Equipment, Nipple up BOPE & function test-good, Test BOPE 250/3000-No Failures, Fluid pack reel, Load hole with 27 bbls, Shut in well for the night. Report Number 2 Report Start Date 7/4/2024 Report End Date 7/5/2024 Last 24hr Summary PJSM, Crew travel to location, Pick up injector & lube, Pick up BHA, Motor & test lube to 3k psi-good, Run in hole, Tag @ 3780', Mill, Plug fell to 3790', Unable to mill, Pull out of hole & swap mills, Run in hole & mill cibp, Work plug to 4017', Attempt to Mill thru 4017' (unable to mill stalls & no weight on bit), Drop 7/16" ball & open circ sub, Kick in N2 & unload till n2 at pits, Pull out of hole,Secure well, Rig down lube & injector, Report Number 3 Report Start Date 7/5/2024 Report End Date 7/6/2024 Last 24hr Summary PJSM, Crew travel to location, Check wellhead pressure on tubing, Pressure up to 1500 psi, Shut in & secure well, Rig down & release coil tubing. Report Number 4 Report Start Date 7/6/2024 Report End Date 7/7/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up, PIck up lube & CCL/GPT, Pressure test to 250/3000 psi-good, Run in hole & tag @ 3971', Fluid level @ 3060', Pull out of hole & secure well, Rig down for the night. Report Number 5 Report Start Date 7/26/2024 Report End Date 7/27/2024 Last 24hr Summary PJSM, Crew travel to location, Spot in & rig up N2, Pick up lube & make up strip guns, stab onto well, Run in hole to perf BEL D6 3890-3902, Pull out of hole & pick up gun #2, Run in & perf D5 (3868-3878), Pull out of the hole, Pick up run #3, Run in hole & perf D5 (3863-3868), Pull out of the hole, Pick up run #4, RUn in hole & perf D4 (3830-3838), Pull out of the hole, Pick up run # 5, Run in hole & perf D3 (3807-3817), Pull out of the hole, Rig down & release AK Eline. Field: Beluga River Sundry #: 324-353 State: Alaska Rig/Service:Permit to Drill (PTD) #:162-037Permit to Drill (PTD) #:162-037 Wellbore API/UWI:50-283-10023-00-00 _____________________________________________________________________________________ Updated by DMA 08-09-24 SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00-00 36 16 7 RKB to MSL = 104 RKB to GL = 14.4 TMD = 5,300 TVD = 5,300 PBMD = 3,752 PBTVD = 3,752 Max Angle = 1 deg @ 1,590 TOC @ 2960 10-3/4 P1 3 4 5/6 7 8 9 10 12 13 14 15 A A B B C D D E F F .25 control line2 11 Could not pass 4038 (2019 CTU FCO) CASING DETAIL Size Type WT Grade Conn ID Btm 36''Conductor 43' 16''Surface 75#J-55 8rd 15.124''302' 10-3/4"Intermediate 55.5#N-80 S8R 9.76''1,831' 10-3/4"Intermediate 51#N-80 S8R 9.85''2,240' 7''Production Casing 23#N-80 Butt 6.366''4,675' TUBING DETAILS 3.5"Production String 9.3#J-55 EUE 8rd, AB 2.992''3,747 2-3/8"Production Tailpipe 4.7#N-80 EUE 8rd 1.995''4,573' JEWELRY DETAIL Production Tubing ID. Depth MD (ft.) ID (in.) Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer / SA 6 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 7 2,817 3 Shear out Safety joint, 57k shear 8 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 9 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 10 3,747 2.406 Baker 5-22 Snap Latch SA / Baker 'DB' Packer perm w MOE 11 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 12 3,791 1.875 Otis 'X' Nipple 13 4,017 CIBP 7/4/2024 14 4,571 1.79 Otis 'XN' Nipple 15 4,572 Baker Wireline Entry Guide Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 4,629 - Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,231' 3,264' 3,231' 3,264' 33' 12 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357' 31' 12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513' 60' 12 12/13/1988 Grvl Pck C 3,562' 3,666' 3,562' 3,666' 63' 12 12/13/1988 Grvl Pck D 3,696' 3,734' 3,696' 3,734' 23' 12 12/13/1988 Grvl Pck D3 3,807 3,817 3,807 3,817 104 7/26/2024 Open D4 3,830 3,838 3,830 3,838 84 7/26/2024 Open D5 3,863 3,878 3,863 3,878 154 7/26/2024 Open D6 3,890 3,902 3,890 3,902 124 7/26/2024 Open E 4,048' 4,058' 4,048' 4,058' 10' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/96 Nolan Vlahovich Hilcorp Alaska, LLC Geotech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: (907) 564-4558 E-mail: nolan.vlahovich@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal. Received By: Date: Date: 8/13/2024 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 SFTP DATA TRANSMITTAL T#20240813 Well API #PTD #Log Date Log Company Log Type AOGCC Eset# BRU 222-24 50283201800000 22Ϭ043 8/1/2024 AK E-LINE CIBP BRU 222-26 50283201950000 224035 7/21/2024 AK E-LINE Plug BRU 232-04 50283100230000 162037 7/25/2024 AK E-LINE Perf BRU 241-26 50283201970000 224068 7/24/2024 AK E-LINE CBL BRU 241-26 50283201970000 224068 7/31/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/10/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/18/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/23/2024 AK E-LINE CBL BRU 241-34S 50283201980000 224077 7/28/2024 AK E-LINE Hoist IRU 44-36 50283200890000 193022 8/3/2024 AK E-LINE CBL IRU 44-36 50283200890000 193022 7/31/2024 AK E-LINE CIBP IRU 44-36 50283200890000 193022 7/29/2024 AK E-LINE RCT MPU I-01 50029220650000 190090 7/20/2024 AK E-LINE CBL MRU M-02 50733203890000 187061 7/20/2024 AK E-LINE Plug PBU PTM P1-08A 50029223840100 202199 7/23/2024 AK E-LINE CBL PBU V-220 50029233830000 208020 6/28/2024 READ InjectionProfileAnalysis PTU DW-01 50089200320000 214206 7/16/2024 READ CaliperSurvey PTU DW-0ϭ 50089200320000 214206 7/17/2024 READ TemperatureSurvey Please include current contact information if different from above. T39418 T39419 T39420 T39421 T39421 T39422 T39422 T39422 T39422 T39423 T39423 T39423 T39424 T39425 T39426 T39427 T39428 T39428 BRU 232-04 50283100230000 162037 7/25/2024 AK E-LINE Perf Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.13 13:58:22 -08'00' 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: CTCO, N2 2.Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 5,300'N/A Casing Collapse Structural Conductor Surface 1,020psi Intermediate 3,220psi Production 3,830psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng jake.flora@hilcorp.com 907-777-8442 Noel Nocas, Operations Manager 907-564-5278 Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: 3-1/2" PRESENT WELL CONDITION SUMMARY Jake Flora, Operations Engineer AOGCC USE ONLY Tubing Grade: 9.3# / J-55 Tubing MD (ft): 3,747'Perforation Depth TVD (ft): Subsequent Form Required: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 029656 162-037 50-283-10023-00-00 Hilcorp Alaska, LLC Proposed Pools: 4.7# / N-80 TVD Burst 4,573' 6,340psi 302' Size 29' 10-3/4"2,226' 288' MD See Attached Schematic 5,860psi 2,630psi 43' 2,240' 43' 302' July 1, 2024 2-3/8" 4,675' Perforation Depth MD (ft): 2,240' 3800 Centerpoint Drive, Suite 1400 Anchorage, Alaska 99503 Beluga River Unit (BRU) 232-04CO 802 Same 4,675'7" ~1,529psi 4,661' N/A Length Bkr SC 1L GP Pkr; Bkr DB Perm Pkr; N/A 2,793' MD/TVD; 3,748' MD/TVD; N/A, N/A 5,300'4,629'4,629' Beluga River Sterling-Beluga Gas 36" 16" See Attached Schematic m n P s 66 t 2 N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Noel Nocas (4361) DN: cn=Noel Nocas (4361) Date: 2024.06.19 14:04:18 - 08'00' Noel Nocas (4361) 324-353 By Grace Christianson at 2:32 pm, Jun 19, 2024 Perforate DSR-6/21/24 X 10-404 CT BOP test to 3000 psi SFD 7/1/2024BJM 6/27/24 July 1, 2024 *&: Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2024.07.01 14:32:13 -08'00'07/01/24 RBDMS JSB 070224 Well Prognosis Well Name: BRU 232-04 API Number: 50-283-10023-00 Current Status: SI Gas Producer Permit to Drill Number: 162-037 First Call Engineer: Jake Flora (907) 777-8442 (720) 988-5375 (C) Second Call Engineer: Chad Helgeson (907) 777-8405 (907) 229-4824 (C) Maximum Expected BHP: ~ 1,699 psi @ 3,888’ TVD (Calc’d W/ .437 psi/ft gradient) Max. Predicted Surface Pressure: ~ 1,529 psi (BHP minus 0.1 psi/ft. gas grad.) Well Status SI Gas Producer, last production 2018 Brief Well Summary Originally drilled in early 1963 and completed in the Beluga F, G and H with a single string and a heater string. A workover in 1988 added the Sterling and Beluga A through D intervals with a gravel pack over the newly added sands. BRU 232-04 is a single 3-1/2” production string to 2,791’ w/ gravel pack screen from 2,793’ to 3,747’. A plug was set in the well isolating the Beluga E and F sands in 2009 at 3,791’ (in the X nipple). The well was flowing 1.8-2 MMscfd and would not come back on after a shutdown in late December of 2017. In June of 2019 a coil cleanout was performed on the well which made it down to 4,038’ and encountered a solid obstruction. In 2020 a CIBP was set below the lower straddle to isolate the E & F sands, followed by an unsuccessful attempt to swab the well online. The purpose of this work/ sundry is to clean out the well with coil tubing, and perforate Beluga sands through the tubing tail. Notes Regarding Wellbore Condition x Vertical wellbore x Last tag was @ 3,815’ WLM, on 10-29-2020 Procedure 1. Provide AOGCC 48hrs notice of BOP test 2. MIRU CTU, pressure test BOPs to 3000 psi 3. Load well with water, perform fill cleanout, mill plug at 3773’, clean out as deep as possible 4. Blow wellbore dry with nitrogen, RDMO CTU 5. MIRU E-line, PT lubricator to 3,000 psi 6. Perforate sands within the below gross interval: Sand MD Top MD Base TVD Top TVD Base Date Top Sterling/Beluga Gas Pool 3166’ 3166’ Beluga D3 – E5 3807’ 4200’ 3807’ 4200’ Proposed a. Proposed perf interval lies within the existing perforation interval. b. If any zone produces sand and/or water or needs isolated, RIH and set plug above the perforations OR patch across the perforations. c. If fill is encountered during testing, coil tubing will be placed on the well as per above approved BOP test pressures to perform a fill cleanout. Well Prognosis 7. Return well to production Attachments: 1. Actual Schematic 2. Proposed Schematic 3. Coil BOP Diagram 4. Standard Nitrogen procedure _____________________________________________________________________________________ Updated by: JMF 06-12-24 SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = 3,752’ PBTVD = 3,752’ Max Angle = 1 deg @ 1,590’ TOC @ 2960’ 10-3/4” P1 3 4 5/6 7 8 9 10 12 13 14 15 A A B B C D E F F .25” control line2 11 Could not pass 4038’ (2019 CTU FCO) CASING DETAIL Size Type WT Grade Conn ID Btm 36''Conductor 43' 16''Surface 75#J-55 8rd 15.124''302' 10-3/4"Intermediate 55.5#N-80 S8R 9.76''1,831' 10-3/4"Intermediate 51#N-80 S8R 9.85''2,240' 7''Production Casing 23#N-80 Butt 6.366''4,675' TUBING DETAILS 3.5"Production String 9.3#J-55 EUE 8rd, AB 2.992''3,747’ 2-3/8"Production Tailpipe 4.7#N-80 EUE 8rd 1.995''4,573' JEWELRY DETAIL Production Tubing ID.Depth MD (ft.)ID (in.)Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer / SA 6 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 7 2,817 3 Shear out Safety joint, 57k shear 8 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 9 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 10 3,747 2.406 Baker 5-22 Snap Latch SA / Baker 'DB' Packer perm w MOE 11 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 12 3,773 CIBP w 21’ cement – TOC @ 3,752’ (12/23/20) 13 3,791 1.875 Otis 'X' Nipple 14 4,571 1.79 Otis 'XN' Nipple 15 4,572 Baker Wireline Entry Guide Plugs/Other ID.Depth MD (ft.)ID (in.)Description P1 4,629 -Float Collar PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status A 3,231' 3,264' 3,231' 3,264'33'12 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357'31'12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513'60'12 12/13/1988 Grvl Pck C 3,562'3,666'3,562'3,666'63'12 12/13/1988 Grvl Pck D 3,696'3,734'3,696'3,734'23'12 12/13/1988 Grvl Pck E 4,048' 4,058' 4,048' 4,058'10'16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227'7'16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450'7'16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/96 _____________________________________________________________________________________ Updated by: JMF 06-17-24 PROPOSED Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5300’ TVD = 5300’ PBTD = 4629’ MD / TVD’ Max Angle = 1 deg @ 1590’ TOC @ 2960’ 10-3/4” 3 4 5/6 7 8 9 10 12 13 14 A A B B C D E F F .25” control line2 11 CASING DETAIL Size Type WT Grade Conn ID Btm 36''Conductor 43' 16''Surface 75#J-55 8rd 15.124''302' 10-3/4"Intermediate 55.5#N-80 S8R 9.76''1,831' 10-3/4"Intermediate 51#N-80 S8R 9.85''2,240' 7''Production Casing 23#N-80 Butt 6.366''4,675' TUBING DETAILS 3.5"Production String 9.3#J-55 EUE 8rd, AB 2.992''3,747’ 2-3/8"Production Tailpipe 4.7#N-80 EUE 8rd 1.995''4,573' JEWELRY DETAIL Production Tubing ID.Depth MD (ft.)ID (in.)Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer / SA 6 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 7 2,817 3 Shear out Safety joint, 57k shear 8 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 9 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 10 3,747 2.406 Baker 5-22 Snap Latch SA / Baker 'DB' Packer perm w MOE 11 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 12 3,791 1.875 Otis 'X' Nipple 13 4,571 1.79 Otis 'XN' Nipple 14 4,572 Baker Wireline Entry Guide PERFORATION DETAIL Sands Top (MD)Btm (MD)Top (TVD)Btm (TVD)Amt SPF Date Status A 3,231' 3,264' 3,231' 3,264'33'12 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357'31'12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513'60'12 12/13/1988 Grvl Pck C 3,562'3,666'3,562'3,666'63'12 12/13/1988 Grvl Pck D 3,696'3,734'3,696'3,734'23'12 12/13/1988 Grvl Pck D-E 3870’ 4200’ 3807’ 4200’ TBD Proposed E 4,048' 4,058' 4,048' 4,058'10'16 12/10/1988 Rig Perf, RWO reperf E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Rig Perf, RWO reperf F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Rig Perf, RWO reperf F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf STANDARD WELL PROCEDURE NITROGEN OPERATIONS 12/08/2015 FINAL v1 Page 1 of 1 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre-Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4-gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures O2 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. Samuel Gebert Hilcorp Alaska, LLC GeoTechnician 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 04/09/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL BRU 232-04 (PTD 162-037) PLUG SET RECORD 12/23/2020 Please include current contact information if different from above. PTD: 1620370 E-Set: 34957 Received by the AOGCC 04/09/2021 04/12/2021 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic and printed data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 5,300 feet 3,773 feet true vertical 5,300 feet N/A feet Effective Depth measured 3,752' feet 2793 & 3748 feet true vertical 3,752 feet 2793 & 3748 feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3# / J-55 2,791' MD 2,791' TVD Tubing (size, grade, measured and true vertical depth)2-3/8" 4.7# / N-80 4,573' MD 4,573' TVD Bkr SC 1L GP Pkr; 2,793' MD/TVD Packers and SSSV (type, measured and true vertical depth)Bkr DB Perm Pkr; N/A 3,748' MD/TVD N/A; N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 43' 302' 0 Oil-Bbl measured true vertical Packer 7"4,675' 2,240' 4,675' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Beluga River Field / Undefined Gas PoolN/A measured TVD Tubing Pressure 00 Beluga River Unit (BRU) 232-04 N/A FEDA-029656 2,240' Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 162-037 50-283-10023-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-480 10 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 50 Authorized Signature with date: Authorized Name: 40 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 29' 288' 2,226' 4,661' Conductor Surface Intermediate Production 3,830psi Casing Structural 36" 16" 10-3/4" Length 5,860psi 2,630psi Collapse 1,020psi 3,220psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 6,340psi 43' 302' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 12:23 pm, Mar 23, 2021 Digitally signed by Taylor Wellman (2143) DN: cn=Taylor Wellman (2143), ou=Users Date: 2021.03.23 12:07:33 -08'00' Taylor Wellman (2143) RBDMS HEW 3/26/2021 SFD 3/24/2021BJM 4/26/21 DSR-3/23/21 Rig Start Date End Date 12/22/20 3/5/21 Hilcorp Alaska, LLC Well Operations Summary API Number Well Permit NumberWell Name BRU 232-04 50-283-10023-00-00 162-037 Swabbed for 4 days with no progress. Called the job over. 12/23/2020 - Wednesday JSA, PTW, MIRU and PT lubricator. RIH w/ 1.75" Star Bit Correlate to Schematic and tag @ 3,771'. Send correlation log data to town to verify depths. Make up 2-3/8" cast iron bridge plug. RIH set plug at 3,773' to of plug. Dump 10' of sand on top of the plug @ 1.6 Gallons in 2-3/8" tubing. Dump 11' of cement (3.2 GA in 2-3/8" and 3-1/2" tubing). TOC = 3,752'. RDMO. End ticket. 03/05/2021 - Friday Daily Operations: 12/22/2020 - Tuesday On weather hold to travel to Beluga. Arrive in Beluga. Prep AK E-line equipment. Dump 11' of cement Dump 10' of sand on top of the plug @ Make up 2-3/8" cast iron bridge plug. RIH set plug at 3,773' to of plug. _____________________________________________________________________________________ Updated by: DMA 03-08-21 SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = 3,752’ PBTVD = 3,752’ Max Angle = 1 deg @ 1,590’ Tubing Min ID = 1.79” TOC @3,305” 10-3/4” P1 3 4 5/6 7 8 10 11 12 13 14/15 16/16A 17 18 19 A A B B C D E E F F F .25” control line 2 9 CASING DETAIL Size Type WT Grade Conn ID Btm 36'' Conductor 43' 16'' Surface 75# J-55 8rd 15.124'' 302' 10-3/4" Intermediate 55.5# N-80 S8R 9.76'' 1,831' 10-3/4" Intermediate 51# N-80 S8R 9.85'' 2,240' 7'' Production Casing 23# N-80 Butt 6.366'' 4,675' TUBING DETAILS 3.5" Production String 9.3# J-55 EUE 8rd, AB 2.992'' 3,747’ 2-3/8" Production Tailpipe 4.7# N-80 EUE 8rd 1.995'' 4,573' JEWELRY DETAIL Production Tubing ID. Depth MD (ft.) ID (in.) Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,791 3 Baker Seal Locator Assembly 6 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer 7 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 8 2,816 3 XO, 5" 8rd box x 3.5" 10rd pin 9 2,817 3 Shear out Safety joint, 57k shear 10 2,818 2.992 3.5" 9.2# 10rd Pipe w/ centralizers (344 ft.) 11 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 12 3,737 1.9 O' Ring Seal Sub 13 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 14 3,747 2.406 Baker 5-22 Snap Latch Assembly w/ 2 seal units 15 3,748 3.25 Baker 'DB' Packer permanent w/ mill out extension 16 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 16A 3,773 CIBP w 21’ cement – TOC @ 3,752’ (12/23/20) 17 3,791 1.875 Otis 'X' Nipple 18 4,571 1.79 Otix 'XN' Nipple 19 4,572 Baker Wireline Entry Guide Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 4,629 - Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,231' 3,264' 3,231' 3,264' 33' 12 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357' 31' 12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513' 60' 12 12/13/1988 Grvl Pck C 3,562' 3,666' 3,562' 3,666' 63' 12 12/13/1988 Grvl Pck D 3,696' 3,734' 3,696' 3,734' 23' 12 12/13/1988 Grvl Pck E 4,048' 4,058' 4,048' 4,058' 10' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/96 CIBP w/ 10' sand + 11' of cement, TOC at 3752' MD. - bjm 1.Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: ___________________ 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6.API Number: 7.If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10. Field/Pool(s): 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 5,300'N/A Casing Collapse Structural Conductor Surface 1,020psi Intermediate 3,220psi Production 3,830psi Liner Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Bkr DB Perm. Pkr TVD =3748 12. Attachments:Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16.Verbal Approval:Date:GAS WAG GSTOR SPLUG Commission Representative: GINJ Op Shutdown Abandoned Taylor Wellman 777-8449 Contact Name: Ted Kramer Operations Manager Contact Email: Contact Phone: 777-8420 Date: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng Authorized Title: 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Signature: November 20, 2020 2-3/8" BKR SC 1L GP Packers, No SSSV Perforation Depth MD (ft): 2,240' See Attached Schematic 4,661' MD=2793' TVD=2793' MD= 3,748' , 7" 36" 16" 29' 10-3/4"2,226' 288' 43' 302' 2,240' 43' 302' 4,675'4,675' 4.7# / N-80 TVD Burst 4,573' 6,340psi MD 5,860psi 2,630psi Hilcorp Alaska, LLC 3800 Centerpoint Dr, Suite 1400 Anchorage Alaska 99503 PRESENT WELL CONDITION SUMMARY STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 FEDA 029656 162-037 50-283-10023-00-00 Beluga River Unit (BRU) 232-04 Beluga River Unit / Undefined Gas Pool State Wide Spacing COMMISSION USE ONLY Authorized Name: Tubing Grade: 9.3# / J-55 Tubing MD (ft): 3,747' See Attached Schematic tkramer@hilcorp.com 5,300'4,629'4,629'1,529 N/A Perforation Depth TVD (ft):Tubing Size: 3-1/2" Length Size m n P 66 t _ Form 10-403 Revised 3/2020 Approved application is valid for 12 months from the date of approval. By Samantha Carlisle at 9:26 am, Nov 12, 2020 320-480 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.11.10 09:35:37 -09'00' Taylor Wellman *Alternate plug placement approved per 20 AAC 25.112(i) gls 11/16/20 Plug Perforations DLB11/12/2020 DSR=11/13/2020 10-404X GAS Comm 11/17/2020 dts 11/16/2020 JLC 11/16/2020 RBDMS HEW 11/17/2020 Well Prognosis Well: BRU 232-04 Date: 11/04/2020 Well Name: BRU 232-04 API Number: 50-283-10023-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 11/23/2020 Rig: E-line Reg. Approval Req’d? Yes Date Reg. Approval Rec’vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 162-037 First Call Engineer: Ted Kramer (907) 777-8420 (O) (987) 867-0665 (M) Second Call Engineer: Todd Sidoti (907) 777-8443 (O) (907) 632-4113 (C) AFE Number: Current Surface Pressure: ~ 165 psi Maximum Expected BHP: ~ 1,699 psi @ 3,888’ TVD (Calc’d W/ .437 psi/ft gradient) Max. Predicted Surface Pressure: ~ 1,529 psi (BHP minus 0.1 psi/ft. gas grad.) Brief Well Summary Originally drilled in early 1963 and completed in the Beluga F, G and H with a single string and a heater string. A workover in 1988 added the Sterling and Beluga A through D intervals with a gravel pack over the newly added sands. BRU 232-04 is a single 3-1/2” production string to 2,791’ w/ gravel pack screen from 2,793’ to 3,747’. A plug was set in the well isolating the Beluga E and F sands in 2009 at 3,791’ (in the X nipple). The well was flowing 1.8-2 MMscfd and would not come back on after a shutdown in late December of 2017. In June of 2019 a coil cleanout was performed on the well which made it down to 4,038’ and encountered a solid obstruction. The purpose of this work is to set a plug @ 3,780’ and place cement on top to isolate the E sands. Hilcorp requests a waiver from 20 AAC 25.112 (c) (1) E, which states that a plug cannot be set more than 50‘ above the top of a perforated interval. Here the plug will be set 268’ above the top perforation of the E sands to take advantage of the mechanical packer providing a mechanical barrier with cement on top of it and alleviates the problem of the perforations being behind a tubing tail. Notes Regarding Wellbore Condition x Well is currently off line. x Min ID to encounter in this work is 1.995” @ 3,758’ ( XO from 4-1/2” to 2-3/8” tubing) x Min ID in the well is is 1.79” (Otis “XN” Nipple @ 4,571’MD) x Last tag was @ 3,815’ WLM, on 10-29-2020 E-line Procedure: 1. MIRU lubricator and pressure test the same to 250 psi low / 3,000 psi high. 2. PU RIH W/ 2-3/8” CIBP to 3780’. Set same. POH. 3. PU Bailer. RIH and dump 25’ of cement up to 3,755’ RD MO E-line. 4. Turn well over to production. Attachments: 1. Current Schematic 2. Proposed Schematic (CTU tag was 4038' in June 2019) _____________________________________________________________________________________ Updated by: DMA 07-16-19 SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = 4,629’ PBTVD = 4,629’ Max Angle = 1 deg @ 1,590’ Tubing Min ID = 1.79” TOC @3,305” 10-3/4” P1 3 4 5/6 7 8 10 11 12 13 14/15 16 17 18 19 A A B B C D E E F F F .25” control line 2 9 CASING DETAIL Size Type WT Grade Conn ID Btm 36'' Conductor 43' 16'' Surface 75# J-55 8rd 15.124'' 302' 10-3/4" Intermediate 55.5# N-80 S8R 9.76'' 1,831' 10-3/4" Intermediate 51# N-80 S8R 9.85'' 2,240' 7'' Production Casing 23# N-80 Butt 6.366'' 4,675' TUBING DETAILS 3.5" Production String 9.3# J-55 EUE 8rd, AB 2.992'' 3,747' 2-3/8" Production Tailpipe 4.7# N-80 EUE 8rd 1.995'' 4,573' JEWELRY DETAIL Production Tubing ID. Depth MD (ft.) ID (in.) Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,791 3 Baker Seal Locator Assembly 6 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer 7 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 8 2,816 3 XO, 5" 8rd box x 3.5" 10rd pin 9 2,817 3 Shear out Safety joint, 57k shear 10 2,818 2.992 3.5" 9.2# 10rd Pipe w/ centralizers (344 ft.) 11 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 12 3,737 1.9 O' Ring Seal Sub 13 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 14 3,747 2.406 Baker 5-22 Snap Latch Assembly w/ 2 seal units 15 3,748 3.25 Baker 'DB' Packer permanent w/ mill out extension 16 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 17 3,791 1.875 Otis 'X' Nipple 18 4,571 1.79 Otix 'XN' Nipple 19 4,572 Baker Wireline Entry Guide Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 4,629 - Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,231' 3,264' 3,231' 3,264' 33' 12 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357' 31' 12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513' 60' 12 12/13/1988 Grvl Pck C 3,562' 3,666' 3,562' 3,666' 63' 12 12/13/1988 Grvl Pck D 3,696' 3,734' 3,696' 3,734' 23' 12 12/13/1988 Grvl Pck E 4,048' 4,058' 4,048' 4,058' 10' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/96 4048' CTU FCO to 4038' (hard tag) _____________________________________________________________________________________ Updated by: DMA 11-04-20 PROPOSED SCHEMATIC Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00 36” 16” 7” RKB to MSL = 104’ RKB to GL = 14.4’ TMD = 5,300’ TVD = 5,300’ PBMD = ±3,745’ PBTVD = ±3,745’ Max Angle = 1 deg @ 1,590’ Tubing Min ID = 1.79” TOC @3,305” 10-3/4” P1 3 4 5/6 7 8 10 11 12 13 14/15 16/16A 17 18 19 A A B B C D E E F F F .25” control line 2 9 CASING DETAIL Size Type WT Grade Conn ID Btm 36'' Conductor 43' 16'' Surface 75# J-55 8rd 15.124'' 302' 10-3/4" Intermediate 55.5# N-80 S8R 9.76'' 1,831' 10-3/4" Intermediate 51# N-80 S8R 9.85'' 2,240' 7'' Production Casing 23# N-80 Butt 6.366'' 4,675' TUBING DETAILS 3.5" Production String 9.3# J-55 EUE 8rd, AB 2.992'' 3,747’ 2-3/8" Production Tailpipe 4.7# N-80 EUE 8rd 1.995'' 4,573' JEWELRY DETAIL Production Tubing ID. Depth MD (ft.) ID (in.) Description 1 14 WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/ .25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis 'X' Nipple 5 2,791 3 Baker Seal Locator Assembly 6 2,793 4 Baker SC-1L 7084-40 Gravel-Pack Packer 7 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 8 2,816 3 XO, 5" 8rd box x 3.5" 10rd pin 9 2,817 3 Shear out Safety joint, 57k shear 10 2,818 2.992 3.5" 9.2# 10rd Pipe w/ centralizers (344 ft.) 11 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 12 3,737 1.9 O' Ring Seal Sub 13 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 14 3,747 2.406 Baker 5-22 Snap Latch Assembly w/ 2 seal units 15 3,748 3.25 Baker 'DB' Packer permanent w/ mill out extension 16 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 16A 3,770 CIBP w ~25’ cement – TOC @~3,745’ 17 3,791 1.875 Otis 'X' Nipple 18 4,571 1.79 Otix 'XN' Nipple 19 4,572 Baker Wireline Entry Guide Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 4,629 - Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,231' 3,264' 3,231' 3,264' 33' 12 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357' 31' 12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513' 60' 12 12/13/1988 Grvl Pck C 3,562' 3,666' 3,562' 3,666' 63' 12 12/13/1988 Grvl Pck D 3,696' 3,734' 3,696' 3,734' 23' 12 12/13/1988 Grvl Pck E 4,048' 4,058' 4,048' 4,058' 10' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/96 CIBP w/cmt cap STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Sjl e Wv 4 i JUL 16 2[11; A s^r r, rz ; ' 1. Operations Abandon Ll Plug Perforations Ll Fracture Stimulate Li Pull Tubing Li `Operations shutdown Li Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CTCO w N2 pull plug 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory ❑ Service ❑ 162-037 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50-283-10023-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA-029656 Beluga River Unit (BRU) 232-04 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Beluga River Field / Undefined Gas Pool 11. Present Well Condition Summary: Total Depth measured 5,300 feet Plugs measured N/A feet true vertical 5,300 feet Junk measured N/A feet Effective Depth measured 4,629' feet Packer measured 2793 & 3748 feet true vertical 4,629' feet true vertical 2793 & 3748 feel Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 36" 43' 43' Surface 288' 16" 302' 302' 2,630psi 1,020psi Intermediate 2,226' 10-3/4" 2,240' 2,240' 5,860psi 3,220psi Production 4,661' 7" 4,675' 4,675' 6,340psi 3,830psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic 3-1/2" 9.3# / J-55 2,791' MD 2,791' TVD Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.7# / N-80 4,573' MD 4,573' TVD Bur SC 1L GP Pkr; 2,793' MD/ VD Packers and SSSV (type, measured and true vertical depth) Bkr DB Perm Pkr; N/A 3,748' MD/TVD N/A; N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 70 40 Subse1:1 0 0 0 75 22 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas WDSPL LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-579 Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: lkramer(a�hilcoro.com Authorized Signature: D Dater I Contact Phone: 777-8420 Form 10-404 Revised 4/2017 7y/gy� � � � �� RBDMS �JUL 18 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 232-04 CTU 1 50-283-10023-00-00 162-037 1 6/14/19 1 6/16/19 Daily Operations: 06/14/2019 - Friday PTW, JSA. Finish de mobe from BRU 233-27. MIRU SLB CTU 13 on BRU 232-04. Lay pit liner, spot equipment. Fill supply tank with 300 bbls. Rig up iron, data cables, Install BOPE. Fill Nitrogen tank. BOPE testing in the morning. 06/15/2019-Saturday PJSM. PTW. Location walk around complete. 24 hr BOPE test witness notification sent 6/14/19 @ 0600 hrs. Start BOPE test. Draw down test. Test all rams and valves to 250/4,000 psi. No Failures. Stab 40' of lubricator. Make up BHA. all tools 1-11/16". Coil dimple connector, check valves, disconnect, accelerator, weight bar, jars, JDC overshot. 15.8' long. Stab on well. PT stack 250/4000 psi. RIH. Wegith check at 3,600'5,700 lbs. Slack ofweight 2,136 lbs. Stack on fish at 3,738' Pick up to 6,200 lbs. 500 lbs overpull. Fish on. POOH to surface. Close swab. Pop off well. Fish recovered. Break down slick line tools. Wash nozzle installed. Stab on well. PT stack 250/4,000 psi. RIH. Tag Sk down at 3,983' pumping at 1.5 bbls min. Reel swivel leaking. Need to POOH to surface and replace. POOH to surface. Close master and swab. SLB fixing reel swivel and adjusting wedge plates in reel. Well secure. SDFN. 06/16/2019-Sunday PTW, JSA. Fire equipment. Make up BHA. Stab on well. PT stack 250/4,000 psi. RIH with 1.75" CT and down jet nozzle to 4,039'. Stack 5k down. weight broke back and circ pressure dropped from 3,650 to 1,700 psi. Lost returns. Plck up on CT. Fire up N2 truck. RIH tag at 4,033'. Returns back to surface for about 15 minutes. Pick up RIH at 100'a minute and smack down at 4,033'. Set 10k down. Knocked something loose. Lost returns again. Obstruction is not acting like debris/ fill. Weight does not wash off when jetting. Circ pressure does not increase while jetting. PT N2 lines 250/4,000 psi. Online down coil with N2 at 800 scf/min. POOH slowly until N2 kicks off to surface. 2,855' CTMD N2 and fluid at surface. Trip back in hole unloading wellbore. Tagged 3k down at 4,038'. Pump n2 at bottom to unload wellbore. 4 hrs pumping N2 from bottom. returns have light sands. Formation is unloading about 3 bbls per hour. Small readings of Gas at surface. 3- 15% LEL. POOH to surface. Shut down N2 at 3,500'. Close in choke. WHP 508 psi. Tagged up. Rig down SLB CTU 13. Bring well online to open top tank. Brought well to 0 psi to tank. 20 % LEL. Shut in well to allow for build up. SLB rigged down. Mobilize equipment to BRU 212-18. K cora Aleeka. LLC PBMD=4,629' PBTVD=4,629' Max Angle = 1 deg @ 1,590' rol line SCHEMATIC CASING DETAII Beluga River Unit Well: BRU 232-04 Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00 Size Type WT Grade Conn ID Btm 36" Conductor 2,016 2.9 Chemical Injection Mandrel, 3.5"xl" w/.25" control line 1 43' 16" Surface 75# 1-558rd 2.75 15.124" 302' 30-3/4" Intermediate 55.5# N-80 58R 9.76" 1,831' 10-3/4" Intermediate 51# N-80 S811 9.85" 2,240' 7" Production Casing 23# N-80 Butt 6.366" 4,675' TUBING DETAILS JEWELRY DETAIL Production Tubine ID. Depth MD (ft.) ID (in.) Description 1 14 SPF WKM 3.5" Tubing Hangerw/Cameron type'H'BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"xl" w/.25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-21/5" DV w/ RK latch 4 2,758 2.75 Otis'X' Nipple 5 2,791 3 Baker Seal Locator Assembly 6 2,793 4 Baker SC -1L 7084-40 Gravel -Pack Packer 7 2,797 4.77 Baker 'S' Perforated Extension/Lower Seal Bore 8 2,816 3 X0, 5" 8rd box x 3.5" lord pin 9 2,817 3 Shear out Safety joint, 57k shear 10 2,818 2.992 3.5" 9.2# lord Pipe w/ centralizers (344 ft.) 11 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 12 3,737 1.9 0' Ring Seal Sub 13 3,7372.992 E Tell Tail Screen .006 Gauge w/ Centralizers 14 3,747 2.406 Baker 5-22 Snap Latch Assembly w/ 2 seal units 15 3,748 3.25 Baker'DB' Packer permanent w/ mill out extension 16 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 17 3,791 1.875 Otis'X' Nipple 18 4,571 1.79 Otix'XN' Nipple 19 4,572 16 Baker Wireline Entry Guide Plugs/Other ID. Depth MD (ft.) ID (in.) Description P3 4,629 - li Float Collar PERFORATION DETAII Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF I Date Status A 3,231' 3,264' 3,231' 3,264' 33' 1 12 1 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357' 31' 12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513' 60' 12 12/13/1988 GwI Pck C 3,562' 3,666' 3,562' 3,666' 63' 12 12/13/1988 Grvl Pck D 3,696' 3,734' 3,696' 3,734 23' 12 12/13/1988 Grvl Pck E 4,048' 4,058' 4,048' 4,058' 10' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Rig Perf, RWO reperf& tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Rig Perf'RWO reperf& tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Peril RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1985 Rig Perf, RWO reperf& tbg. Plug set, pulled 6/96 Updated by: DMA 07-16-19 ffil.wp -1044.4m. UA: DATE 3/27/2019 161037 Debra Oudean Hilcorp Alaska, LLC GeoTech 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 30 5 13 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: doudean@hilcorp.com To: Alaska Oil & Gas Conservation Commission Natural Resources Technician 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL CD: J] BRU 232-04 ACX 06MAY18 StopAboveP... [� BRU 232-484 ACX 06MAY18_StopAcrossS... BRU 232-04 ACK_06MAY18_StopAcrossS... BRU 232-04ACX 06MAY18 StopAcrossS... BRU_232-484_.4CX 06MAY18 StopAcrossS... n BRU 232-04ACX_06MAY1S_StopAcrossS... BRU_232-484 ACX_06MAY18 StopAcrossS... BRU_232-04 ACX 06MAY18 StopAcrossS... BRU 232-04 ACX_06MAY18_StopAcrossS... BRU_232-04_PPROF_06MAY18 BRU 232-04 WaterConformance 06MAY18 BRU 232-04 WaterConformance 06MAY... RECEIVED MAR 2 8 2019 AOGCC 6I22,201810:02AM LAS File 61221201 S 9:55 AM DLIS File 6/22,12018 10:01 AM LAS File 6/22120189:55A.M DEIS File 6/22/201 S 10:01 AM LAS File 6/22/201S 9:55 AM HIS File 6/22/201 3 10.00 AM LAS File 6/22/20159:55 AM DUS File 6,/22/20159:59 AM LAS File 5,22/201811:19 AM LAS File 6J22;20139:57AM LAS File 5/29/20154:10 PM PDF Document Please include current contact information if different from above. Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 . -a THE STnO 'ALASKA GOVERNOR MIKE DUNLEAVY 0 Alaska Oil and Gas Conservation Commission Chad Helgeson Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 $LANK& DE P, Re: Beluga River Field, Undefined Gas Pool, BRU 232-04 Permit to Drill Number: 162-037 Sundry Number: 318-579 Dear Mr. Helgeson: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. 4-L DATED this 2 (Oday of December, 2018. Sincerely, Hollis S. French Chair RBDMS-�-) DEC 2 81018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: CTCO w N2 pull plug Q 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ itoZ - 0', ) 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-10023-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes E]No Q BRU 232-04 9. Property Designation (Lease Number): 10. Field/Pool(s): A-029656 I I Beluga River Field / Undefined Gas Pool . 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 5,300' 5,300' 4,629' 4,629' -2,800psi none none Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 36" 43' 43' Surface 288' 16" 302' 302' Intermediate 2226' 10.75" 2240' 2240' Production 4661 7" 4675' 4675' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): From 3,181-4,545' 3181-4585 3-1/2" J-55 4,572' Packers and SSSV Type: BKR SC 1 L GP Packers, No SSSV Packers and SSSV MD (ft) and TVD (ft): MD=2793' TVD=2793' MD= 3,748', Bkr DB Perm. Pkr TVD =3748 12. Attachments: Proposal Summary Q Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development ❑✓ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: January 3, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑/ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Chad Helgeson 777-8405 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramerlcahilcorp.com Contact Phone: 777-8420 Authorized Signature•" Date: �ti Zv8 u COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: i Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,aoo 1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No,� Subsequent Form Required: / U - 01Lf LQ2�_�APPROVED BY ll alp Approved by: COMMISSIONER THE COMMISSION Date: RBDMS�� DEC 2 8 2018 � A -'- /L�, -/ S Form 10-403 Revised 4/2017 Approved application i�v,�ir'hr>� to of approval. Submit Form and Attachments in_Duplicate • • Well Prognosis Well: BRU 232-04 Hilcorp Alaska, LLQ Date: 12/20/2018 Well Name: BRU 232-04 API Number: 50-283-10023-00 Current Status: Gas Producer Leg: N/A Estimated Start Date: 01/05/2019 Rig: CTU Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 162-037 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Surface Pressure: 165 psi Maximum Expected BHP: 1,69 3,888' TVD (Calc'd W/.437 psi/ft gradient) Max. Predicted Surface Pressure: (While Pumping Nitrogen) Brief Well Summary Originally drilled in early 1963 and completed in the Beluga F, G and H with a single string and a heater string. A workover in 1988 added the Sterling and Beluga A through D intervals with a gravel pack over the newly added sands. BRU 232-04 is a single 3-1/2" production string to 2,791' w/ gravel pack screen from 2,793' to 4,573'. A plug was set in the well isolating the Beluga E and F sands in 2009. The well was flowing 1.8-2 MMscfd and most recently would not come back on after a shutdown in late December of 2017. The purpose of this work is to pull plug @ 3,791' MD, clean out the solids with coil tubing, blow the well dry with nitrogen. Notes Regarding Wellbore Condition • Well is currently off line. • Min ID is 1.79" (Otis "XN" Nipple @ 4,571'MD) • Last tag was @ 3,744' WLM, most likely the fishing neck of the top of plug. (12/07/2018) Coiled Tubing Procedure:+�y 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low.Zv A✓ z S"c, r' �,./ch,,4 " 2. SI well. 3. Route well production to open top diffuser 400 bbl tank. 4. Need to pull plug 5. RIH w/ 1.5" coil w/ jet nozzle BHA. a. Top of fill estimate in tbg tail to be @ ±4,200'. Engage fill and clean out to 4,550' (below bottom perf) using nitrogen if necessary to lift. b. Blow well dry while holding back pressure to prevent more solids from entering well bore. 6. Leave 1,200 psi on well. RDMO CTU. 7. Return well to Production to Bleed off Nitrogen and place back into system. • • Well Prognosis Well: BRU 232-04 Hilcorp Alaska, LLI Date: 12/20/2018 Attachments: 1. Current Schematic 2. Coil BOPE Schematic 3. Standard Well Procedure- Nitrogen 4. CT Flow Schematic (Forward) • Hileorp Alaska, LLC RKB to MSL = 104' RKB to GL = 14.4' TMD = 5,300' TVD = 5,300' PBMD=4,629' PBTVD=4,629'j' Max Angle = 1 deg @ 1,590' • Beluga River Unit Well: BRU 232-04 SCHEMATIC Last Completed: 12/19/1988 PTD: 162-037 API: 50-283-10023-00 CASING DETAIL Size Type WT Grade Conn ID Btm 36" Conductor 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/.25" control line 3 43' 16" Surface 75# J-55 8rd 15.124" 302' 30-3/4" Intermediate 55.5# N-80 S8R 9.76" 1,831' 30-3/4" Intermediate 51# N-80 S8R 9.85" 2,240' 7" Production Casing 1 23# N-80 Butt 6.366" 4,675' trol line TUBING DETAILS 3.5" Production String 9.3# J-55 EUE 8rd, AB 2.992" 2,791- 2-3/8" Production Tailpipe 4.7# N-80 EUE 8rd 1.995" 4,573' JEWELRY DETAIL Production Tubing ID. Depth MD (ft.) ID (in.) Description 1 14 SPF WKM 3.5" Tubing Hanger w/ Cameron type 'H' BPV 2 2,016 2.9 Chemical Injection Mandrel, 3.5"x1" w/.25" control line 3 2,718 2.9 Gas Lift Mandrel, 3.5"x1.5" Camco MMG-2 1/5" DV w/ RK latch 4 2,758 2.75 Otis'X' Nipple 5 2,791 3 Baker Seal Locator Assembly 6 2,793 4 Baker SC -1L 7084-40 Gravel -Pack Packer 7 2,797 4.77 Baker's' Perforated Extension/Lower Seal Bore 8 2,816 3 XO, 5" 8rd box x 3.5" 10rd pin 9 2,817 3 Shear out Safety joint, 57k shear 10 2,818 2.992 3.5" 9.2# 10rd Pipe w/ centralizers (344 ft.) 11 3,162 2.992 Welded Screen .006 gauge w/ centralizers (574 ft.) 12 3,737 1.9 O' Ring Seal Sub 13 3,737 2.992 Tell Tail Screen .006 Gauge w/ Centralizers 14 3,747 2.406 Baker 5-22 Snap Latch Assembly w/ 2 seal units 15 3,748 3.25 Baker'DB' Packer permanent w/ mill out extension 16 3,758 1.995 XO, 4.5" 8rd box x 2-3/8" 17 3,791 1.875 Otis'X' Nipple (plug in X -nipple) 18 4,571 1.79 Otix'XN' Nipple 19 4,572 16 Baker Wireline Entry Guide Q (� Plugs/Other ID. Depth MD (ft.) ID (in.) Description P1 4,629 Float Collar PERFORATION DETAIL Sands Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,231' 3,264' 3,231' 3,264' 33' 12 12/13/1988 Grvl Pck A 3,300' 3,357' 3,300' 3,357' 31' 12 12/13/1988 Grvl Pck B 3,404' 3,513' 3,404' 3,513' 60' 12 12/13/1988 Grvl Pck C 3,562' 3,666' 3,562' 3,666' 63' 12 12/13/1988 Grvl Pck D 3,696' 3,734' 3,696' 3,734' 23' 12 12/13/1988 Grvl Pck E 4,048' 4,058' 4,048' 4,058' 10' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/92 E 4,220' 4,227' 4,220' 4,227' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/93 F 4,443' 4,450' 4,443' 4,450' 7' 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/94 F 4,489' 4,503' 4,489' 4,503' 14 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/95 F 4,538' 4,545' 4,538' 4,545' 7 16 12/10/1988 Rig Perf, RWO reperf & tbg. Plug set, pulled 6/96 Created By:JEK 2/9/2017 Kill Pnr WH PSI 2" 1502 x2 -1/1f Flanged Val, (Manual) 2-1/16 1 OK x 10K Ranged (Manual Coil Tubing BOP Coiled Tubing HR580 Injector Head & Gooseneck Weight= 12,850 lbs 4-1/16" 10K Conventional Stripper 5K C062 Lubricator 5K C062 x 4-1/16" 1 OK Flange 4-1/16" 10K Combi BOP Top Set: Blind/Shear Second Set: Pipe/Slip 4-1/16" 1 O Flow Cross Manua 2x2 Valve 1: 2" 1502 x 2-1/16" 10K Flange Manua 2x2 Valve 2: 2-1/16" 10Kx2-1/16" 10K Flange Manual 2x2 Valve 3: 2-1/16" 10K x 2-1/16" 10K Flange Manua 2x2 Valve 4: 2" 1502 x 2-1/16" 10K Flange 4-1/16" 1 O x Wellhead Adapter Flange Wellhead 11 STANDARD WELL PROCEDURE rfiIeorpAlaska. LLC NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -Job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/02 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL v1 Page 1 of 1 Open—Tap Tank w/ Diffuser s up Annulus) COILED TUBING UNIT 1,12 JETTING FLOW SCHEMATIC 10,000,000 1,000,000 L C CO C w100,000 CL LL V ,O ++ H m 10,000 f0 _ 4 0 O to }+ m a, Ci LL 1,000 u B 3 V cOa 100 a 3 O L N 10 HILCORP ALASKA LLC, BELUGA RIV UNIT 232-04 (162-037) BELUGA RIVER, UNDEFINED GAS Monthly Production Rates 10,000,000 W v 1,000,000 N O �h O 100,000 K O 3 S 10,000 0 1 W N 1,000 y O m 100 m Z O 3 rr 10 O' 1 4— 1 Jan -1965 Jan -1970 Jan -1975 Jan -1980 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSHEET_Prod-I nject_Curves_WeIl_Vll7_1620370_BRU_232-04_20181221.xlsx 12/21/2018 r • • STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon LJ Plug Perforations LJ Fracture Stimulate LJ Pull Tubing LJ Operations shutdown U Performed: Suspend ❑ Perforate H Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ .rforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: 5e} ,t`%C \) 9 H 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑., Exploratory ❑ 162-037 3.Address: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic❑ Service ❑ 6.API Number: 50-283-10023-00 7.Property Designation(Lease Number): 8.Well Name and Number: A-029656 BRU 232-04 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Beluga River Field/Beluga Pool/Undefined Gas 11.Present Well Condition Summary: Total Depth measured 5300 feet Plugs measured 3732.7,3788 feet true vertical 5300 feet Junk measured none feet Effective Depth measured 4629 feet Packer measured 2793,3748 feet true vertical 4629 feet true vertical 2793,3748 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 36" 43' 43' Surface 288' 16" 302' 302' Intermediate 2226' 10.75" 2240' 2240' RECEIVED Production 4661' 7" 4675' 4675' Liner MAR 1 8 2016 Perforation depth Measured depth 3181'-4545' feet 2016 Af'1��JJ ��.//GC�"! True Vertical depth 3181'-4545' feet APR 1 9 6 Tubing(size,grade,measured and true vertical depth) 3.5" J-55 4572' 4572' Packers and SSSV(type,measured and true vertical depth) Baker SC-IL Gravel Pack Packer 2793' 2793' Baker DB Permanent Packer 3748' 3748' 12.Stimulation or cement squeeze summary: Intervals treated(measured): No stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A 0 0 160 psi 480 psi Subsequent to operation: N/A 500 40 160 psi 100 psi 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development D Service ❑ Stratigraphic H Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas E WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP H SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-355 ` p 1 Contact t V\ 4agl';1N4�l' 5�e.'C1 Email A\\'\, tl' q•2y i� -` )�e�'�a)@J con\ ,w\c; (`(,,Vvnco�A,��' r Printed Name (( [ Title f v�( JJW td c E.y�5i n eR'./ C om Signature Phone q01- 22' - 91-4Date 'IN ?P x 4i-4—lei Form 10-404 Revised 5/2015 / 4'470 RBDMS VV MAR 2 1 2016 Submit Original Only • • Daily Operation for 232-04 6/11/2015 SET AD-2 STOP, PACKOFF PLUG & AA STOP (3736.4' - 3730.7' KB) @ BOTTOM OF 3-1/2" GP SCREEN & ABOVE 2-3/8" TAILPIPE -_ .a 3 SAK PROD 0 BRU 232-04 ConocoP fillips 01 Well Attributes Max Angle&MD TD AI:3ska.Inc YealltEra CPIUOI Fiala Name Weems Statue 11t3I I MC IttIS B1 Aet EST Ott EI ,,,,,„„maps BELUGA RIVER UNIT PROD --_ 5.320 3 ••• Cc.rmant I1ZS;pprI Data Annotation Eni 1:4e KE•-.:49;NI RIC REIEEGE Cato _c_---`..•-..:333.3•,• SSSS NCNE ,. ._: 5: .-c 22-355 -Annatatmn Da*lttKEI Elia Cats Annotation LastM_:e.; .,..".Cala Las:Tag.RKE 3.7&: 4.':,2:-3 Rev Reasc hJJ'_JO --- - WIio.Y.,apQ4 m:,aw I I i Casing Strings AA Caelrg Dae=npti^.r 3C:Int IC:In 1 Top;AKEI Sat Cap!,lttKE; Sat Caotn;T CI ',VL an II...vr3,a r:FTs rano ___aum F:Ra,1..=_..a.4aA.A „a.,,� 35DUOTOR42• 2' -a.a 93{ 't=_J EJ r:later C9esag EIr CC,If1 IC In i"152 liKEl Eat Captr(RKEI Eel Ce5tn,TVCI.. IIL I. 5.1353 TsFTnrsal C•E.1v,C.L;iAu.+ al SURFACE 4 -4.4 332 255 SP. lin CaYmg ONBrlpt12r 35. Ir IC Ir: Too;atKEI Set Capin lttKEi Sat Coati MIDI MIKL Sr323 T FTRre3R Iv'=a+. 1+.�:ur:loA INTERMEDIA. E. u. 75: - 2.243.: 2.< 2 M. LR Casing Cae^✓I5II:r CC.Oil IC Ir rap:TIME: Sat Capin lttKEl Sat Cacti,T.'CI PxtLee 1 &363 TEE Tnrg.T Ego 4.1,17.2.712.4ap pJ5-L_'i T ;? ..- 4.675 4.3745 23 `}543 J `I Tubing Strings aaew,rF::.aas.4 ntIr C39zri4ti r String Ma.' ---L ID Too;TYKE: Sat Captn;MWan. Bat Wan Matt I. ',6t :IMF: race 5.52:rtf311:5 J 1 _ -4.4 4._72r 3:J-75 52 E aeaanur,Ims Completion Details NilMVDfFIR.a!IC y.. T__,' 1.:::r.`C1:itKEl 1:51114 I.I tam Cr 2:2T {MI mAcKEIC 2,113s4" '4.4 '_3 HANGER V.,:`,1%E.NG HANGER',CANERCN TYPE-I E=13.533 pec«717.4 t'a 2.7:44 2 74,42 NIPPLE _T :`ts'=_E 2.752 2.3E2 2. 52 E _.32 PACKER._ _A v .4 E_ .._. .o '. 3! 5 . 2.374 2.757. 332 SEE _--:EP=-❑.-...-....FEDE:, ENE._.a__4,EP 3E._ ?E 4.773 ,5Mra+s11:-SicI I 2.3 3,3 2.3 _ 57 SOS SAF ET^' SHEAR CJTSA.FET'fJ DINT 57KSH==-: 3.333 Anew a's!ASSnA I I 3. .r- 3 3.:3 SCREEN WE_ SCR arN--::s 3AJGE-a,CE --..._.255 2.=92 MOW;1,7l113aaseA I I _7334 3.7337 _.27 2-RIN3 CP.,.,._e._3J0 .._" '- -733. 22 3--.=., E__...-E3CR=.7.N G-32..-.54 BE',r.CENT3F._ZE3.3 2.332 A:as:3_aaPPa=44 3.`37.} 3 4S3 Snap Let_r _ o 22_*1.43.:•5:: a-i A=. __f•n:25E3.... 2.4566 J`!T3 A.E.R.a.*UP EZETO 3.743: 374 L. :27 PACKER SAKES D£PER'4ANENT=ACfiR•e Mi..-CUT 3.253 'TEtd5TION ...=a3=.1.04Ai.16n I 4724.: 3.72 - _27 X7Ra ; CROSSOVER 3.5 x 2 375.'3 965..94.7.N-6:. 2.375 EJE3R7 .,_E_ 4242:-.2,.72_-, 3.7=_7 3.__4 3.23 NIPPLE OTISN NIPPLE `.E75 a" a,3-n .=7_.7 -5734 :72 NIPPLE OTISXNNIPPLE 7.: .+.=.42.-•:44i4c -`_72: 4=7 7 2.72 WLEG 'BAKER W?E_1VEEVTR'3410E 2.44- Other in Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) ._aa....-,3E11E- TEE rP,T1 rap Inn Tap InKEI IttKEI ;'I Cr CLT Bart Data 113+I1tI _ ...3.7 2'2.73_.4 3.27 _-OP n--.2'-_ 9:753 4.73.7 3.732.4 2 27 P_JG _ _._ _ 1.:__-i. 5 0.055 .?Ea 3E930vEEED ' 52 734 4 3.734- :.27 3-7P 7.',2'2.3 27- --1= -.__.7:-! 9.75:1 3,753_ 3____ 3.25 PLUG ::.575'i.-_J3 52:.2:-2 62:03 _ _2222 E.sA Perforations&Slots 1531 44a4,4 2 Ai:C4 East Cana s�ti�J✓.n��.r.�..nn.ti2^.nJ 1. _ _. Too:TIC: Etr IT'D I .11Nc111 Too ITLKH; Etc IHKH :515 . 5511 Cora Gets t1 Type '._T : _. : a3o-1aASA 35.6-_3 3.2 : 5407 -7 A,ERU232- L'1'5E3 :2:3 APERF I ! 34 zk.anAP4,71244 • 355-,.:3 3.236.: 3.. __. 2275.7 A•ERU232- 2 33b 2._ APERF m 44:22 7 - _ 7 Ai 3"_ __ /176237127 PW3:3.7na 3,23'......;f 3.264.: ....3.7 <,3.• A.6P.0 232- 2 _ APERF a; n-a g•g.^i.7 _ 34 -.53::3 5.32..: 3.3257 3.323.. A•ERU232 : i3.. 2.. APERF i76:1.73e.a T 34 335:. 3`._ 34,457 3 355.7 A,EP..U232- _ 55 c.= APERF _ - -227GP 34 a-_. :_ =zv l.nan Ii 3,4:4.: 3.4-3: 3 4:3 7 34-_.7 E EAU 232- _. _-355 "2.0 APERF 22 n 34 .71.-C, m ra'374aA 41y 3.423.5. 3,455.: 2.42.2 5452 7 E.EP.U232- _ 3:•966 52.9 APERF ■l-\J 24 PM�q:377 P 3.47.. 3454 3 3 n .47:7 3..-.7 .ER.0 232- _ 3 355 '2:3 APERF • '" - - 34 3. V a.sss.o s 3. 2.7 E.ERU 232- - APERF 34 I 3,562:3 3._54_ 7 3.243.7 O.ERU23c L 3 355 :2,3 APERF '-`. 5-..7„-^22 7,:= 54 Pi, a.7s3n 3.56.6.5 31625._ _134 7 5:524.7 C.BR 232- ..-536 '242 APERF I 34 ...-1-3,4C7 = 3.635:3 3.sa:: 3.537.7 3.54',.7 C E'RU2"32- 4-_-353 2.3 APERF 34 =s..2-r 444714,40a1A 3.632.5 3,663._ 5 3-. ...5_.7 ER 232- L 333 2:5.APERF 34 3332 3.53f5:_ 3 x3..3 = :: 3. _3 7 C.ERU232- '2 _ :35 2._ APER: _ __ _ .. u�.^A 4332. - 24 236¢6 4.441D443GA 3.x724.1 5.734: 3.723 7 3.754 7 D4 ERU 252- -L .33 APE?" - 4,'.45.3 4.353 3 247.7 4.:-'_7.7 E.ERU 232- -_-.- m.3 RPERF :__.-.LIS 2iKO.0 34 _ 4,225.5. 4.227.3 .Z 5.7 4.-25? E.6P,U 232- -6.3 RPERF 442E'2236_-.3262. 34 4,4433 4.45:.: 4.4427 4.443.7 F•6RU232- 4-.-3,4 "63 RPERF 6143_s-.a aa,.C' !:1 34 4,459.1 4,515.: 4,4;;..7 4.5:2.7 F.ERU 232- 535 -5:3 RPERF __7 L.M.0 5.4 4,533.3 4,545 44377 4.=44.7 F,BRU 232- 2 6.5 '6.2 RPERF 34 • •-.,-\\ SANG PROD BRU 232-04 Con©coPhillips Alaska.inc 03447 4 .4c,144 , I I Mandrel inserts "3.JK4M..144.3=.04144..._:- " 'J : 4e T:p;T/C; Vain LetCe. Part En TRO Rio H T: ttKe 1tK2 41343 N 31 CO fief Spry Type Type IIs pets RLr Cae :::r rY:2.4^16t i • l i CAT KELID 'f CHEM DMY EK-2 .D3- ' - 2 A CA'-1,A .444.1-s ":2 iAE-I�' Dt tY RK ""`'i°D Notes:General 8 Safety - -_—.-1y; II E',4 Cete 4.7.:43th4r • OTE-=77 a.RCD CSC:=_C,4-c-_4444..-:z- . t 5 M 2 :rES -EN .4.44F 1181.d34tA4, 1r 1'.2.181 C2d>i.G I 4..4 1.42,04M4444 I • =E.,1130441,3374 R ?Ei'3.4046341,12 4 4 4444 d.1."'144.44514 244:SESE 2.1 .4 ?.G=1 4C1 O34444 0 4E2=35:4443124 ▪?E2=3520-:.4144 E2 .....:5455 III ▪4E2 ...-44 4 444^✓._'�/. J..MJLAJU.�.� �'✓.J1.r� ?E247.6.5.5..'5S ii ii 2'=- I 1704-.1,411.4 Ell -._4,-5-5.5 l i PACKER 1444 U V I I 2=.2=444E_4:]344 ..4OOr.445254'5 woo :4,4446-4,44414 .44E24 4 554413022 54E744 43?264345C 1_4_E.45707 t 4R /41.544 437=2 43742 4,44CO-C11:4 144.4VSC X62-031 • • 2-Ca tc WELL LOG TRANSMITTAL DATA LOGGED ' itgi2o15 M. K.BEND€R To: Alaska Oil and Gas Conservation Comm. July 16, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ' A a " i Anchorage, Alaska 99501 AUG, I 3 £UIJ RE: Gravel Pack Evaluation: BRU 232-04 Run Date: 6/24/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 BRU 232-04 Digital Field Log Image file, LAS files, Processed Log Image Files 1 CD Rom 50-283-10023-00 SCANNED PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Mobile: 907-350-8453 FRS_ANC@halliburton.com Date: Signed: Mva-g-a-0.44) .44fe"'-t V OF Ty. • �w\��V/j��s� THE STATE Alaska Oil and Gas 77-1-:--, .. s��,—'1' of kL /` SJ`T /\ Conservation Commission ,• 1 itt2` 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907 279 1433 OFALAS1E'P Fax. 907.276 7542 iit6 20 No 15 www aogcc.alaska.gov v .\\JL v Jay Maguire ��'A 0 9 .3 Wells Engineer \- d"' ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Beluga River Field, Undefined Gas Pool, BRU 232-04 Sundry Number: 315-355 Dear Mr. Maguire: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this Z day of June, 2015 a� Encl. STATE OF ALASKA A KA OIL AND GAS CONSERVATION COM, ;ION � \4 APPLICATION FOR SUNDRY APPROVALS (�� 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Rill Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Set Bridge Plug r 2 Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. • Exploratory r Development r 162-037 3.Address: Stratigraphic r Service r 6 API Number. P.O. Box 100360,Anchorage,Alaska 99510 50-283-10023-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception's Yes r No J' BRU 232-04 9 Property Designation(Lease Number)• 10.Field/Pool(s): p A-029656 - Beluga River Field/Beluga�ivet-eeJLh s Pool U^ n/.J 6c).S '' ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft). Effective Depth TVD(ft). Plugs(measured): Junk(measured): 5300 . 5300 4629'• 4629'• 3788' none Casing Length Size MD TVD Burst Collapse Conductor 29' 36" 43' 43' Surface 288' 16" 302' 302' CI E.i V E 0 Intermediate 2226' 10.75" 2240' 2240' Production 4661 7 4675' 4675' UN D9 L i! ,J AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): from 3181'-4545' , 3181'-4545' 3.5 J-55 _ 4572 Packers and SSSV Type• Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER MODEL SC-IL GRAVEL PACK PACKER MD=2793 TVD=2793 PACKER-BAKER DB PERMANENT PACKER MD=3748 TVD=3748 NO SSSV 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work. Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development . Service r 14 Estimated Date for Commencing Operations: 15. Well Status after proposed work. 6/10/2015 OIL r VVINJ r WDSPL r Suspended r 16-Verbal Approval. Date: GAS F ' WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jay Maguire @ 263-4551 Email: Jay.C.Maquire@conocophillips.com Printed Name Ja Maguire Title. Wells Engineer signature 6 ` Phone:263-4551 Date i,./6 jib i Commission Use Only Sundry Number. Conditions of approval: Notify Commission so that a representative may witness 3(c—355 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other. Spacing Exception Required? Yes ❑ No 12( Subsequent Form Required: /v-1 py / APPROVED BY 1 Approved b . / COMMISSIONER THE COMMISSION Date: /0/12/L-5 Approved application is valid fmonths tram the date of approval. Submit Form and or 12 Form 10-403 Revised 5/2015 ORIGINAL p/ka Qty l l _. " Attachmentfin uplicate �,f RBDMS JUN 2 4 2015 AK ( BRU 232-04 Con©coPhillips A Well Attributes Max Angle&MD 'TD Alaska.In Wellbore APUUWI Field Name Well Status Incl°) MD(ftKB) Act Btm(ftKB) 502831002300 BELUGA RIVER UNIT PROD 1.54 1,500.00 5,300.0 Conioculealtps .°"' Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date Well conng:-BRU 232-04,11/1212012 sm:36 AM SSSV:NONE Last WO: 12/19/1988 501.82 2/2/1963 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 3,968.0 8/19/2011 Rev Reason:WELL REVIEW osborl 11/12/2012 HANGER,14 Casing Strings CONDUCTOR Casing Description String 0... String ID...Top(ftKB) Set Depth It...Set Depth(TVD)...String Wt...String... String Top Thrd 42•Insulated, CONDUCTOR 42" 20 18.000 14.4 43.0 43.0 WELDED 14.43 mmi ewitui ..,. Insulated liwirsmiwz Casing Description String 0... String ID...Top(0KB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 16 15.124 14.4 302.0 302.0 75.00 J-55 8R AL, k Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd CHEMIC 2.016 t - INTERMEDIATE 103/4 9.760 14.4 2,240.0 2,239.7 55.50 N-80 S8R NTERMEDIATE. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String WL..String...String Top Thrd 14-2,240 PRODUCTION 7 6.366 14.4 4,675.0 4,674.7 23.00 N-80 BUTT GASLIFT, _-- TubingStrings '',':1:' 2.718 Tubing Description String0... StringID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String TopThrd TUBING 3.5 x 2.375 3 1/2 2.992 14.4 4,572.3 4,572.0 9.30 J-55 EUE 8RD AB NIPPLE,2,758 Completion Details Ekl Top Depth SEAL ASSY. - (TVD) Top Incl Nonti... 2.791 ) Top(ftKB) (SW 1°) nem Description Comment ID(in) 14.4 14.4 0.00 HANGER WKM TUBING HANGER w/CAMERON TYPE H BPV - 3.500 PACKER.2.793 IMMO 2,758.4 2,758.2 0.19 NIPPLE OTIS X NIPPLE 2.750 SBE.2797 J ( 2,791.2 2,790.9 0.29 SEAL ASSY BAKER SEAL LOCATOR ASSEMBLY 3.000 4 2,793.2 2,792.9 0.30 PACKER BAKER MODEL SC-IL GRAVEL PACK PACKER 4.000 2,797.4 2,797.1 0.31 SBE BAKER S PERFORATED EXTENSION 8 LOWER SEAL BORE 4.770 3.000 SOS SA Z 0Y. t7 2,816.9 2,816.6 0.37 SOS SAFETY SHEAR OUT SAFETY JOINT,57K SHEAR 3,162.4 3,162.1 0.62 SCREEN WELDED SCREEN,0.006 GAUGE w/CENTRALIZER 2.992 APERF, 3,1e1-3,206' 3,736.4 3,736.0 0.18 0-RING 0 RING SEAL SUB 1.900 APERF, 3.181-3,206 3,737.0 3,736.6 0.18 SCREEN TELLTALE SCREEN.006 GAUGE w/CENTRALIZERS 2.992 APERF, - 3,747.0 3,746.6 0.19 Snap Latch BAKER 5-22 SNAP LATCH ASSEMBLY w/2 SEAL UNITS 2.406 3.231-.264 3,748.0 3,747.6 0.19 PACKER BAKER DB PERMANENT PACKER w/MILL OUT EXTENSTION 3.250 APERF,3,330 3,758.0 3,757.6 0.19 XO Redudng CROSSOVER 3.5 x 2.375,ID 1.995,#4.7,N-80,EUE8RD 2.375 APERF, 3,790.7 3,790.4 0.22 NIPPLE OTIS N NIPPLE 1.875 3,3503.357 - -. - - 4,570.7 4,570.4 1.00 NIPPLE OTIS XN NIPPLE 1.790 APERF. 4,572.0 4,571.7 1.00 WLEG BAKER WIRELINE ENTRY GUIDE 2.441 3.404-3,416 -7 Other Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) APERF, -- Top Depth 3.4233.4531 SCREEN,3,162- (TVD) Top Incl -, Top(ftKB) OMB) (') Description Comment Run Date ID(In) APERF, - 3,788.0 3,787.7 0.21 PLUG 1.875"X PLUG 5/20/2012 0.000 3,471-3,464 Perforations&Slots APERF. I -- Shot 3. O,3.513- Top(ND) Btm(ND) Dens Top(ftKB)Mtn(ftKB) (ftKB) (RKB) Zone _ Date (sh... Type Comment APERF. - 3,181.0 3,206.0 3,180.7 3,205.7 A,BRU 232-04 12/13/1988 12.0 APERF 3,562-3,584 - 3,181.0 3,206.0 3,180.7 3,205.7 A,BRU232-04 12/13/1988 12.0 APERF APERF, - -- 3.599-3,625 - 3,231.0 3,264.0 3,230.7 3,263.7 A,BRU 232-04 12/113/1988.12.0 APERF Baker 4.5"gun,22.7 GP shot 3,330.0 3,324.0 3,329.7 3,323.7 A,BRU 232-04 12/13/1988 12.0 APERF APERF, _ - - 3,638-3.649 , _ 3,350.0 3,357.0 3,349.7 3,356.7 A,BRU 232-04 12/13/1988 12.0 APERF Baker 4.5"gun,22.7 GP shot _ 3,404.0 3,416.0 3,403.7 3,415.7 B,BRU 232-04 12/13/1988 12.0 APERF Baker 4.5"gun,22.7 GP shot APERF, - I 3.662-3666 _ _oAA*L 3,423.0 3,453.0 3,422.7 3,452.7 B,BRU 232-04 12/13/1988 12.0 APERF f'� 3,471.0 3,484.0 3,470.7 3,483.7 B,BRU 232-04 12/13/1988 12.0 APERF APERF, - 6.696-.7os 3,508.0 3,513.0 3,507.7 3,512.7 B,BRU 232-04 12/13/1988 12.0 APERF re APERF, 3,562.0 3,584.0 3,561.7 3,583.7 C,BRU 232-04 12/13/1988 12.0 APERF Baker 4.5"gun,22.7 GP shot 3,724-,734 3599.0 3,625.0 3,598.7 3,624.7 C,BRU 232-04 12/13/1988 12.0 APERF 1,40)4,1,40)4, 0 It'a4 3,,638.0 3,649.0 3,637.7 3,648.7 C,BRU 232-04 12/13/1988 12.0 APERF a Go'rsJ d 3,662.0 3,666.0 3,661.7 3,665.7 C,BRU 232-04 12/13/1988 12.0 APERF SCREEN.3.737 3,696.0 3,709.0 3,695.7 3,708.7 D,BRU 232-04 12/13/1988 12.0 APERF Baker 4.5"gun,22.7 GP shot Snap Latch. • 4 3,724.0 3,734.0 3,723.7 3,733.7 D,BRU 232-04 12/13/1988 12.0 APERF 3.747 4,048.0 4,058.0 4,047,8 4,057.8 E,BRU 232-04 12/1/1988 16.0 RPERF PACKER,3,748 4,220.0 4,227.0' 4,219.7 4,226.7 E,BRU 232-04 12/1/1988 16.0 RPERF a 4,443.0 4,450.0 4,442.7 4,449.7 F,BRU 232-04 12/1/1988 16.0 RPERF . 11 4,489.0 4,503.0 4,488.7 4,502.7 F,BRU 232-04 12/1/1988 16.0 RPERF G.G.3.788 4,538.0 4,545.0 4,537.7 4,544.7 F,BRU232-04 12/1/1988 16.0 RPERF Notes:General&Safety _ End Date Annotation NIPPLE 3,791 . 1/1/2004 NOTE:PBTD @ PROD CSG FLOAT COLLAR 4629' 1/25/2011 NOTE:View Schematic w/Alaska Schemetic9.0 RPERF. 11/12/2012 NOTE:NO TALLY DATA AVAILABLE 4,040.4,058 - - 4,2204,227 _ RPERF, --_ 4.443-4. RPERF, 450 RPERF, -- 4,4894,503 4,53&4, RPERF, 545 1 Ili NIPPLE.4,571 1I- Mandrel Details _ Top Depth Top Port MEG.4.572 7' (ND) Incl OD Valve Lateh Size TRO Run Stn_Top(ftKB (MK ) B) nMake Model (In) Sery Type Tyr)* m e (In) (psi) Run Date Co ... 1 2,016.4 2,016.2 0.56 CAMCO KBUG 1 CHEM DMY BK-2 0.000 0.0 12/1/1988 PRODUCTION, 2 2,718.4 2,718.2 0.06 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 12/20/1988 144.675 TO,5300 232-04: Plug Procedure Well Work Justification&Objectives: (include high-level discussion of objective, not a list of steps) Caliper showed holes in tubing above the current plug set in hole.The well began sand production and we believe the sand is coming from the holes. We will set 3-1/2" packoff plug @ ^'3735'to isolate lower zones below packer.This will be set in the lowest joint of of the 3-1/2" 9.3#gravel pack screen. Hopefully sand production will stop, and we can bring the well back online. Steps: (list service type and include any notifications) Pollard slick line: 1. Spot Pollard Unit on 232-04. Check in with production and field supervisors to confirm the job is safe to conduct. e- 2. RIH with 2.72" drift run to confirm 1.9" restriction is @ 3736' RKB.--,-QA/4 1E41" 5-4C II 3. RIH with 3-1/2"AD-2 stop until you no-go on 1.9" restriction. If you tag at a different depth do not proceed. 4. Pull up to neutral weight on the slickline unit,then pull up 0.5' and set AD-2 stop @ "3736' RKB. 5. RIH with 3-1/2" PX plug and tag AD-2 stop @—3734' RKB. Pull up to neutral weight and set plug. 6. RIH with 3-1/2"AA-2 stop and tag plug @ "3733'. Pull up to neutral weight and set AA-2 stop. 7. RDMO ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 ,~,~ -~ h__. "~ r~ Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman ",,.,. . ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. David W JohnSton Chairman jo/rpc~z-energy ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Rosanne M Jacobsen, Atty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the matedal in these files, please notify the Commission no later than August 8, 1994. Such notification Should include a statement of whether you wish to submit a rebuttal in wdting or at an oral headng and, if the latter, the reasons you believe a written submission would be insufficient. Chairman jo/rpc~z-energy ~'~) r)rinl~'d on recycled paper ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy #610 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open h01e well logs, completion information, including perforation intervals and production data. if you wiSh to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification shOuld include a statement of whether you wish to submit a rebuttal in writing or at an oral headng and, if the latter, the reasons you believe a written submission -----,..._._. David W Johnston \ -" Chairman jo/rpc~z-energy STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION · WELL COMPLETION OR RECOMPLETION REPORT AND LOCi 1. Status of Well ~.~;.~., Classification of Service Well OIL [~, SUSPENDED [] ABANDONED [] SERVICE r-I , ,, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. ~ ~ ~ ' 6~ 3. Address 8. APl Number P.O. Box 100360. Anchoraoe. AK 99510-0360 50- N/A '"--*'~" ' ^'~'~~OL~3IOuL300 4. Location of well at surface 9. Unit or Lease Name 1990' FNL, 1987' FEL, Sec. 4, T12N, R10W, SM Beluga River Unit At Top Producing Interval 10. Well Number 1990' FNL, 1987' FEL, Sec. 4, T12N, R10W, SM BRU 232-4 At Total Depth 11. Field and Pool 1990' FNL, 1987' FEL, Sec. 4, T12N, R10W, SM Beluga River 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 104'I A-029656 12. Date Spudded01/04/63 13. Date T.D. Reached01/24/63 14' Date Comp" Susp' °r Aband' ! 15' Water Depth' if °fish°re [ 16' N°' °f C°mpleti°ns02/02/63* N/A feet MS L 1 17. Total Depth (M D+TV D)5300,MD&TVD 18. Plug Back Depth (MD+TVD)46291ND&TVD YES 19. Directional Survey [] NO [] !20' Depth where SSSV set None feet MD I21 ' Thickness Of PermafrOst N/A 22. Type Electric or Other Logs Run DIL, Sonic Log, Microlog/Cal, FDC, Dipmeter, CBL¢ Neutron~ HFT~ HCT~ CDL/GR/CCL~ GR/CCL/Photon 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 36,, ...... Surf 29' ...... 16" 75# J-55 Surf 302 ' 26" 600 sx 10-3/~" 55.5/51# N-80 Surf 2240' 14-3/4" 1300 sx 7" 23# N-80 Surf 4675 ' 9-5/8" 725 sx 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) See attached _~-1/2"/2-_~/R" 4~7~' ?7Q~' · 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. N/A PRODUCTION TEST Date First Production [ Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR el L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED=~. OIL-BBL GAS-MCF W~TER-BBL OIL GRAVITY-APl (cor;) Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ware r. Submit core chips. RECEIVED None Alaska .0il & Gas Cons. · NOTE= Workover performed, reperforated and added perforations 12/19/88. ' '~n Form 10-407 WC5/072 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate ~~. 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Zone A 3190'-3356' 3190'-3356' N/A Zone B 3403 ' -3514 ' 3403 ' -3514 ' Zone C 3548'-3666' 3548'-3666' Zone D 3697 ' -3708' 3697 ' -3708' Zone E 4048'-4227' 4048'-4227' Zone F 4443 ' -4595 ' 4443 ' -4595 ' -- 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correc! to the best of my knowledge Signed TitleArea Drilling Engineer Date /y2~7/,/~_.,~ 'INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. item 5' Indicate which elevation is Used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool Well Completion or Recompletion Report and Log (Continued) BRU 232-4 Item 24 Perforation Depths' Perforated w/12 spf MD/TVD 3181 -3206 3231 -3264 3330 -3324 3350 -3357 3404 -3416 3423 -3453 3471 -3484 3508 -3513 3562 -3584 3599 -3625 3638 -3649 3662 -3666 3696 -3709 3724 -3734 4048 -4058 4220 -4227 4443 -4450 4489 -4503 4538'-4545 084/SW03 COMPLETION REPORT - NEW WELL o~,^;~.,~.on "~"~°~' OPeraTiONS, INC. - OP.~.~ATOR. ;~ ~-~'.,~,.~,~ OIL CO~A.I~f OF CALIFORNIA - ~:.o ~,,~ AREA: Cook Inlet, Alaska PROP~TY: Beluga River Unit ~[ELL NO.: Beluga River Unit #232-4 LAND OFFICE: Anchorage LEASE NO.: A-029656 Sectioh 4, TownshiP .12 North, Range 10 West, Seward B & M LOCATION: Surface: 1990' South and 1987' West from Northeast Corner of Section 4 (Projected) ELEVATION: 104' K.B.= K. B. is 15' above ground DATE MAY 30' 1963 BY: C. V. C~L~TT"~ON' Dist;ic~'superin~endenf DRILLED BY: Coastal Drilling Company, Rig #3 DATE COE~NCED DRILLING: January. 4, 1963 DATE COMPLETED DRILLING: February 2, 1963 DATE OF INITIAL PRODUCTION: None. Shut-in gas well. SU~f~[ARY TOTAL DEPTH: 5,300' JUNK': None CASING: 36" cemented at 29' 16" cemented at 302' lO 3/4" cemented at 2240' 7" cemented at 4675' PLUGS: 4629' - 4675' COMPLETION REPORT BELUGA RIVER UNIT 232-4 Section 4, T. 12 N., R. lO W., Se. ward B & M STANDARD OIL COMPANY OF CALIFORNIA, W. O. I. - OPERATOR Page 2 PERFORATING RECORD: Four 1/2" holes/foot 4048'-4058' '~ " " " " 4220'-4227' ~ " " " " 4443'-4450' 7 " " " " 4489'-4503' f~ " " " " 4538'-4545' (T~sted) WELL SURVEYS: 1. Schlumberger 2e II e Il e II ® Il 6e II 7- 8. Baroid Daily Induction-Electrical log Sonic log Microlog-Caliper Formation Density log Continuous Dipmeter Cement Bond log Neutron Collar log Mudlog 302'-5305' 2240'-5300' 302'-5303' 2240'-5303' 2240'-5303' !50'-4629' 2400~-462'8' 304'-5300' DRILL STEM TESTS: HFT #1, open hole test 2984'-3027' HCT #1, perforated interval 4538'-4545' COMPLETION REPORT BELUGA RIVER UNIT 232-4 Section 4, T. 12 N., R. 10 W., Seward B & M STANDARD OIL CO~A~Z OF CALIFORNIA, W. O. I. - OPERATOR Page 3 January4- 5,.~963 Spudded at 9:30 P.M. and drilled 14 3/4" hole to 237'. January ~, ~963. Drilled 14 3/4" hole to 304' and opened to 26" to 200' and 20" to 304' Circulated. January ~? 1963 Ran 16", 75#, J-55 8R Rg 3 casing to 302' and cemented through 2 3/8" tubing hung at 278' with 600 sacks cement. Located top of cement 15' below rotary table. Stood cemented. January 8, 1963 74 pcf mud Installed Class IV BOPE. January In~,~.~a.n~ tested BOPE January 10-11, 1963 Drilled cement 264'-304' and drilled 14 3/4" hole to 1597' 75-76 pcf mud J~nuaryl2, 1963 Drilled 14 3/4" hole to 1900'. Ran Schlumber'~ar Induction-Electrical log 301'-1900'. Drilled 14 3/4" hole to 2013'. January 13, 1963 Drilled 14 3/4" hole to 2240''. and Microlog-Caliper 302'-2242'. Circulated. January .14, .196.3 Circulated and conditioned mud. Ran 10 3/4" casing. 75-77 pcf mud 77 pcf mud Ran Induction-Electrical log 1900'-22~2' COMPLETION REPORT BELUGA RIVER 232-4 Section 4~ T. 12 N.~ R. 10 W.~ .Seward. B & M STANDARD OIL COMPANY OF CALIFORNIA, W. O. I. - OPiRATOR PAGE 4 January 15, 1963 CEmeNTING DETAIL Cemented/0,3/4" casing at 2240' with 1200 sacks cement around shoe. Displaced cement with 1148 cu. ft. drilling fluid. Bumped plug with 2000 psi, Cemented annulus through l" pipe bund at 100' with 100 sacks cement. CASING DETAIL Above K.B. 4.99' Cut and recovered 22.25' K. B. to top of casing ~2-~' 44 joints l0 3/4", 55.5", N-80, S8R R3 1813.80' l0 joints l0 3/4", 51#, N-80, S8R R3 including shoe and float collar 408.94 Casing cemented at 22-~0.00 January 16, 1963 Reinstalled and tested B0?Ewith 3000 psi - Okay. Drilled out cement and shoe at 2240'. Drilled 9 5/8" hole to 2491'. 77 pcf mud Jauuary 17,_1963 Drilled 9 5/8" hole to 2860'. Ran Induction-Electrical log 2240'-2863'. Drille'd 9 5/8" hole to 2876". 76-77 pcf mud January 18,..1963 Drilled 9 5/8" hole to 2917' and 8 1/2" hole to 3027'. Ran Induction- Electrical log 2863 '-3031', Formation Density log 2240 '-3029', Sonic log 2240'-3029 ', and Microlog-Caliper 2240'-3032 '. Conditioned mud. 77 pcf mud January 19, 1963 Halliburton Formation Test #1 of the interval 2984'-3027'. Tool Assembly: shoe, two outside BT recorders, 31' oerforated tail pipe, one inside BT recorder (Total 39' of perforations), Safety- joint, two 8" single end wall packers (on 6' centers), safety joint, hydraulic jars, one inside BT recorder, hydrospring tester with 5/8" bean, and dual closed-in pressure valve. Ran on 2686' of 4 1/2" FH drill pipe and 273' of 6" and 7" drill collars. Used no water cushion. (HFT c~ntinued) COmPLETIONs. REPORT BELUGA RIVER UNIT 232-4 Section 4, T. 12 N., R. 10 W.., Seward B & M STANDARD OIL CO~PA~ OF CALIFORNIA, W~ O. I. OPERATOR Page 5 Halliburton Formation Test #1 of the interval 2984'-3027'. Set Packers, Top at 2978', bottom at 2984' v~th 43' of tail to 3027' at 9:05 A.M. Tool opened at 9:09 A.M. and rotated to close in for initial shut-in pressure at 9:10 A.M. Took 16 minute initial shut-in pressure. Opened tool to surface at 9:26 A.M. for 31 minute flow period. Immediate moderate blow of air. Turned to flare at 9:35 A-i~'~., would not b~mrn. Did not burn throughout flow period, no gas to surface. Flow appeared steady throughOut flow period. Pulled pa~cker loose at 9:~7 A.M. Recovered 10~0' net rise, top 1~0' drilling fluid, wt. 72 pcf. Next 900' muddy water grading to clear water. Fresh, salinity 1~%. Water was slightly bubbly as each stand was broken. No cdor of gas. Water contained some fine to very fine grained sand throughout, with a 20'+ medium to coarse grained sand plug above the tool. Final Pressure data: Depth Gauge IH ISI IF FF FH Top inside 296h' 1~1 13--~ ~ 70-~ ' ' 1~4 Bottom inside 2968' 1647 1313 522 706 1638 Top outside 2987'~oo~, 1657 1316,~ 1194 1307 1648 Bottom outside 3024' 1672 1328 1210 1321 1661 Conclusion: Charts indicate tool functioned properly. Flow pressure differences resulted from sand entry as well was flowing. Tester or Perfs showed no plugging. Sand plug in recovery resulted when sand settled while pulling out of hole. Test Conslusive. Pulled tester. ~ened 8 1/2" hole to 9 5/8'' and drilled 9 .5/8" hole to 3280'. 77-78 pcf mud J~anuary 20r22, ,19,6~3~ Drilied 9 ~/$" hole to 76-77 pcf mud January 23, 1963 Ran Induction-Electrical log 3031'-~000' and Formation Density log 3029 ~OOl'.' Drilled 9 ~/8" hole to ~238~ ??-78 pc£ mud COMPLETION REPORT BELUGA RIVER UNIT 232-4 Section 4, T. 12 N.~ R. 10 W., Seward B & M STAMDARD OIL COMPANY OF CALIFORNIA, W. O. I. - OPERATOR Page 6 January 24., 1963 Drilled 9 5/8" hole to 5300'. Ran Induction-Electrical log 5~90'-5305', Formation Density log 2900'-5298', Sonic log 3028'-5300' and ~,~crolog- Caliper 3032 '-5303 '., 78 pcf mud January 2.5, 196~. Ran Continuous Dipmeter 2240'-5296'. Conditioned hole and ran 7" casing 77.5 pcf mud January 26~ 1963 Cemented 7" casing at 4675' with 525 sacks cement around shoe and 200 sacks cement through DV collar at 2002'. CASING DETAIL Above K. B. Cut and recovered K. B. to landing flange 48 joints 7", 23#, N-80 BT R3 DV collar 63 joints 7", 23#, N-80 BT R3 Float collar 1 joint 7", 23#, N-80 BT R3 Float shoe Casing cemented at - 6.45' 22.52' 16.07' 16.07' 1984.14' 2000,.21' 2.06' 2002.27' 2626.63' 4628.90' 1.50' 4630.40' 42.76' 4673.16' 1.84' 4675.00' 4675.06' Removed BOPE and landed casing. January 27, 1963~ Reinstalled BOPE and tested with 3000 psi - Okay. Drilled out and tested DV with 3000 psi - Okay. Cleaned out cement to 4625'. Circulated and conditioned mud. January 28, 1963 Ran Schlumberger Cement Bond log 150'-4629' and Neutron log 2400'-4628'. R~m Schlumberger carrier gun and shot four 1/2" holes/foot ~538:-4545'. CO~.~PLETION REPORT BELUGA RIVER UNIT.232-4 Section 4, T. 12, N., R. lOW., Seward B & M STAND~--OiL COMP~ CF-CALIFORNIA, W, 0'~ I. : oPERAT~ Page 7 HCT #1 4538'-4545'- TOOL ASSEMBLY: two outside BT recorders, 5' of 2 7/8" perforated tail pipe, 7" type "C" hookwall packer, VR safety joint, hydraulic jars, two inside BT recorders, hydrospring tester, and dual closed-in valve. Ran on 4450' of 3 1/2" drill pipe. Used no water cushion. Set packer at 4474', with 22' of tail to 4496' at 5:08 P.M. Open tester at 5:12 P.M. for 5 minute pressure release. Immediate moderate blow of air, increasing to strong when shut in. 400 psi at surface when shut in. Shut in tester at 5:17 P.M. for 34 minute ISI pressure period. Opened tool to surface at 5:51 P.M. for 40 minute flow test. Shut in tool at 6:31 P.M. for 39 minute FSI pressure. Pulled packer loose at 7:10 P.M. Immediate strong blow of gas, flare burned immediately. Flare 30'-40' high. Burned for about 10 minutes when rat~hole mud surfaced, putting out flame. Changed surface bean from 1" to 1/2", Flare burned again. Pressure at surface, 1500 psi. Flow appeared steady throughout flow period. No indication of water.. Recovered 40' of net rise, all drilling fluid weighing 79 pounds NOTE '. No facility to measure gas rates and no estimate made. Test was to determine dry gas only. Pressure data: Pepth GauEe IH _. ISI ~ FF FS___~I F__~H Top inside 4461 2478 2139' 1217 1542 2042 2442 Bottom inside 4464~ 2484' ~2140 1238 1560 2045 2444 Top outside 4490' 2492'~ 2138 1295 ~' 1611 2043 2456 Bottom outside 4493~ 2508 2148 1307 1622 2054 2470 Conclusion: Charts indicate tool functioned properly. No indication of plugging. Test conclusive. January.... 2~9,. 19.63 Circulated and conditioned mud. Ran Schlumberger jet carrier gun and shot four 1/2" holes/foot 4503'-4489' 4450'-4443' 4227~-4220' and 4058~-4048~ Ran 6" bit and casing scraper to 4629'. Circulated and conditioned mud. 77 pcf ~d J__a~nuary 30, !963~ Circulated and conditioned mud. Picked 'up and ran 2 3/8" tubing. COMPLETION REPORT BELUGA RIVER UNIT 232-4 ~Segti.0n 4., T. 12 N., R. 10 W., Seward B & M STANDARD OIL COMPANY OF CALIFORNL~ W. O. I. - OPERATOR Page 8 January ~3.1, 1963 Ran 2 3/8" tubing. TJBING DETAIL K. B. to landing flange Landing flange 65 joints 2 3/8", 42#, N-80 8R R2 with beveled collars 60 joints 2 ~/8", 4.7#, N-80 8R R2 Camco slide valve 1 joint 2 3/8", 4.7#, N-80 8R R2 Brown CC safety joint 2 3/8" pu~,,joint 2 3/8" x HS-16-1 packer 2 joints 2 3/8", 4.7#, N-80 8R R2 Oamco B nipple 17 joints 2 3/8", 4.7i'~, N-80 8R R2 Venturi shoe Tubing landed at K.B. Depth 14.40' · 50' 14.90' 2046.19' 2061.09' 1834.67' 3895.76' 2.72' 3898.48' 29.62' 3928.10' ,94' 3929.04 8.02' 3937.06' 6.02' 3943.08' 62.79 ' 4005.87 · 92' 4006.79 523.61' 4530.40 .60 4531.00 4531.00' CIRCULATING STRING (HEATER STRING) K. B. to landing flange Landing flange 64 joints 2 3/8", 4.7#, N-80, 8R R2 with beveled collars Thin collar on bottom Tubing landing at 14.40' .50' 14.90' 1977.13' 1992.03' · 40' 1992.43' 1992'43 ' Removed BOPE and installed and tested X-mas tree with 3500 psi-Okay. Displaced mud with oil. Set packer at 3937' and tested tubing and casing -- Okay. Shut well in. 1963 Cleaned up and deiced well til 6:00 P.M. Started flowing well at 7:00 P.M. No rates taken. Deicing. F~bruary 2, 1963 Flow-tested well. Flow rates: COMPLETION REPORT BELUGA RIVER UNIT 232-4 Section 4, T. 12 N,, R. 10 W., Seward B & M ~TAhrDAR~' bIL C@~ANY OF CALIFORNIA, W. O. I. - OPERAT~ Page 9 Flow rates: Time Bean Si ze T.P. ~ -~- , ,, , , , 1.1, 12:30 A.M.- 4:15 A.M. 4:15 A.M.- 7:30 A.M. 7:30 A.M.-IO:30 A.M. 10:45 A.M.-ll:15 A.M. 11:15 A.M.-12:00 M 12:OO M -12:30 P.M. 20/64" 16/64" 28/64" 24/64" 20/64" 1730' psi 1445 psi 1550 psi 1645 psi Rate No gas rate No gas rate 4 oo 775o Meter run was icing and plug- ging up during test. Open flow potential based on above rates 74,000 MCF/D. Shut well in at 12:30 P.M.. Set blanking plug mud bled pressure off well. Set Cosasco plugs in both strings. Rig released at 12:OOmidnight. COMPLETION REPORT BELUGA RIVER UNIT 232-4 Section 4~ T. 12 N., R' lOW.~ Seward B & M STANDARD OIL COI~J~ANY OF CALIFORNIA, W. O. I. - OPERATOR Page 10 DEVIATION DATA 158' oo 45' 304' O© 15' 978' 0° 45' 1590' 1© 00' 3027' 0© 30' 3920' 0© 30' 5000' 1© 00' 5300' 0© 30' Dsm C.A. White . _ ~ · "~' "- Wire Line Well Service i"' ~ ~_i,i' ,'--f'~ 'Box 156 Casper, Wyoming 82601 · · -: - SUBSURFACE PRESSURE SURVEY ~ ; ':rosma~,on ~ '., ~CHF~ DF, KB, etc.) Box 962 Soldotna, Alaska 99669 Area Code 913 Tel. 262-4496 _ Compa.ySTANDARD 0IL COMPANY OF CALIF. Lease BELGUA RIVER Field BELGUA RIVER ( ) Test Date psig ?~_,) ~ .......... .L~_..~".. ................................................... hrs.' ' ng presSUre'. i-'i':! i:':"· .,.,' psig psig oF . :Last 'Test '.'.' - - -- - -?- psig . , . - ~ .. : .~ ' ~ in Flow . ~ hrs bbls/day MCF/day ' ' bbls/day Pressure , ._ Casing .PresSure - · _ . - ps~g psig Well No. 2.32-/4 State ALASFd[ Zerb Point KB, GRD Time Paess., F, psig ~724 1760 1806 1858 ~ 8?0 Static Test 'im Press. ft. At hrs. g~maI ¸5o 0 0 8O ti:. ~. :~'~ ~', ~ ' C. A, White ~o. 962 . · .: ~--:~ ._ . --.~ Wit' L~ne Wet_ 5ervlce $oldotna, Ala~, 99669 Area .¢a~e 913 *'~'~'~ '~ ~ ~ ~ ~ '~ ~';~'~ Welt No.~.~~ _ - . 160 .. · . .. ~ , ,. ~,. · , ,, , ,~ . ,~ . '. '{~'.~~,~0' ~-1' ~ .... ~ : ~: ........ ,'3:~'~::l': ..,~- 1900'-~ ....... '"' ....................... -- : 2' J:j . . ... . GAS/'~'!LL OPEN FLOW POTENTIAL TEST I 4-POINT TEST Test Initial ~'~ Anmlal O DRT Special I B l,,,ia u d,"f 7. -4 I Set @ ......... ' ........ ': '-' ::: ..... ' -: '- )iY~arai~)~ :'Length-~(i~)- ' ',, :.."i~allo .~¢F~'~eE-Bbl;'/ ? [ Liquid (Api) Pipeline Connection [ Type Taps ' Multiple Completion (Dual or Triple) [ Type production from each zone OBSERVED DATA ' Flow Data NO. of Flow (Line) (Orifice) h Press. Press. Temp. s~ 177b- .... FLO%V CALCULATIONS Coeffi. , ,,. Flow Temp. Gravity Compress. L~ NO. cient ----~/h p Pressure Factor Factor Factor Rate of Flow (24 Hr.)Vw m psia F F F .. Q ~iCF/D ~. z4~ o ~. ~ ..... 4. .... .~r° .~.-_ ;~O~'h;'~Z', : %~V':-,;), ~ ~;,~0 ........ PRESSURE CALCULATIONS CERTIFICATE: I, the undersigned, state that I am the of (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and ~direction and that the facts stated therein are true, correct and complete to the best of my knowledge. , Signature Alaska Oil and Gas Conservation Commission Gas Well Open Flow Potential Te~t Report [4-Point Te~t) Form No. G-1 Authorized by Order No. I Effective October 1, 1958 x- . Z32-4 2,' 5 6 7 8 9 10 5 6 7 8 9 10 "*'"" STATE OF ALASKA ~ AL, ...KA OIL AND GAS CONSERVATION COMMIb,.,~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging m Perforate ¢_... Pull tubing m Alter casing ~ Repair well ~ Pull tubing v, 2. Name of Operator ARCO Alaska; Inc. 3. Address P.0. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1990' FNL, 1987' FEL, Sec. 4, T12N, RIOW, SM At top of productive interval 1990' FNL, 1987' FEL, Sec. 4, T12N, RIOW, SM At effective depth 1990' FNL, 1987' FEL, Sec. 4, T12N, RIOW, SM At total depth 1990' FNL, 1987' FEL, Sec. 4, T12N, RIOW, SM Other ~ Workover 6. Datum elevation (DF or KB) RKB loaf' 7. Unit or Property name Beluga River Unit feet 8. Well number BRU 23 2-4 9. Permit number/approval number 8-694 -10. APl number 50-- N/A 11. Field/Pool Beluga River 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 5300 'MD feet 5300 ' TVD feet 4629 'MD feet 4629'TVD feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Plugs (measured) Junk (measured) Size Cemented 29' 36" - - 302 ' 16" 600 sx 2223' 10-3/4" 1300 sx 4659 ' 7" 725 sx measured See attached See attached true vertical 4629' - 4675' None Measured depth 29'MD 302'MD 2240'MD 4675'MD True vertical depth 29'TVD 302'TVD 2240'TVD 4675'TVD Tubing (size, grade, and measured depth) 3-1/2"/2-3/8", J-55/N-80, tbg w/tail (~ 4573' Packers and SSSV (type and measured depth) 'SC-IL'Gravel pack pkr ~ 2793' & Baker 'DB' pkr (~ 3748', SSSV: 13. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure P, ECEIVED JAr,,[ ~ 1 i9~o. A.~aska.0il & Gas Cons. ,Commission 14. N/A Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation ./'-"'"'-.. Copies of Logs and Surveys run __ Daily Report of Well Operations ~, "x,,,Oil ~ ~) Gas ~ Suspended 17. I hereby certify that the foregoing is true and correct to th~f my knowledge. Service Form 10-404 Rev 06/15/88 Title Area Drilling Engineer * Workover Well History (Dani) SW04/O01 Date //2 7F/~? SUBMIT IN DUPLICATE Report of sundry Well Operations (Continued) BRU 232-4 Block 12 perforation Depths Perforated w/12 spf 3181'-3206' 3231'-3264' 3330'-3324' 3350'-3357' 3404'-3416' 3423'-3453' 3471'-3484' 3508'-3513' 3562'-3584' 3599'-3625' 3638'-3649' 3662'-3666' 3696'-3709' 3724'-3734' 4048'-4058' 4220'-4227' 4443'-4450' 4489'-4503' 4538'-4545' RECEIVED jAH ~ 1 19~'~ LAlaska Oil & Gas Cons. ComlllJs,sjoil : ~chorage 084/SW03 ARCv Oil and Gas Company Well History - Initial Report - Daily Prepare and submit the 'Initial Rel~rl" on the firet Wednelda¥ life, a well II ipudded or workover Op~F&;|ons ire Itltted. DiII)~ work prior to IPuddlng Ihould be lummarlzed on the form giving Inclullve dltel Duly. District ARCO Alaska, Inc. Field Beluga River l~unty, ~rish or ~ro~h Cook Inlet Leau or Unit A-029656 Title Workover ell no. RU 232-4 Auth. or W,O. no. AD 6315 Operator ARco Spudded or W.O. begun IDate IH°ur Acdept. I 12/03/88 I 1530 hfs Date and depth Complete ~cord for each day re~ed aeo, 8:~ a.m. ROLL+I~I #5 RD AND MOVE RIG TO BRU 232-4. IARCO W.I, 0.0000 Prior Itatul if a W.O. 12/03/88 TD: 5300' PBD: 4629' SUPV: SS 12/04/88 TD: 5300' PBD: 4629' SUPV: SS 12/05/88 TD: 5300' PBD: 4629' SUPV: SS 12/06/88 PBD: 4629' SUPV: SS 12/07/88 PBD: 4629' SUPV: SS 12/08/88 PBD: 4629' SUPV: DL 12/09/88 PBD: 4629' SUPV: DL 12/10/88 PBD: 4629' SUPV: DL 12/11/88 PBD: 4629' SUPV: DL 12/12/88 PBD: 4629' SUPV: DL The above is correct · For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. FIN MOVING RIG. ACCEPT RIG ~ 1530 HRS 12-3-88. STRING. CUT PROD STRING @ 3914' W/CHEM CUTTER. WELL. KILL PROD CIRC & KILL FIN KILL WELL. NU BOPS. RAISE SUB, RU FLOOR. TEST BOPS. FIN RU FLOOR, BELL NIPPLE AND FLOWLINE. FIN RU FLOOR. POH & LD HEATER STRING. POH & LD PROD STRING TO CHEMICAL CUT. GIH W/OS, PU DP. GIH, PU DP. W/5 ROUNDS. RETR TOOL. TAG FISH @ 3914' & CATCH SAME. PU & ROT. FISH FREE POH - REC CUT JT & 'CC' SAFETY JT TOP. GIW W/'CC' CATCH FISH & ROTATE FREE. POH. POH LD FISH. RIT W/BIT & SCRAPERS. CO FILL F/4537' TO 4629'. CIRC & FILTER BRINE. POH ABOVE PERFS. RIH. REV. CIRC. WELL. DROP RABBIT. POH W/BIT. POH. RU ATLAS WL. CONVEYED PERF GUNS. LINES TO 2500 PSI. RUN CDL/GR/CCL F/4629' to 703' RIH W/ TBG RU ATLAS. SET PKR. TEST FLO~ HEAD & PERF BELUGA W/12 SPF, F/4048-4058', 4220'-4227', 4443'-4450', 4489'-4503', & 4538'-4545' FLOW UNTIL BRINE ~ SURFACE STTD- 900 PSI. RELEASE PKR. RE~. CIRC TO KILL WELL. POH. LD PERF ASS'Y. RIH W/BIT AND SCRAPERTO 4626' CIRC WELL CLEAN. RAISE WT TO 9.3 PPG WHILE FILTERING. POH W/~IT. FINISH POH W/BIT. RIH W/RBP & SET @ 4000' TEST CSG TO 2000 PSI. PUMP SAND SWEEP. SPOT 4 SX SAND ON RBP. HANG OFF DP. ND BOP & TBG. NU NEW HEAD & TEST. NU BOP. NU BOPE. TEST TO 3000 PSI. PULL STORM PKR. POH W/DP. RESET WEAR RING. REDRESS 2 PERF GUNS. RIH W/TBG CONVEYED PERF ASS'Y. RU ATLAS WL. IDate 5 AR3B-459-1-D aNumber all dally well hlltory forms Gon~ecutlvely jPege no. · they ere prepared for each well. ARC~ 011 and Gas Company Dally Well History--Interim This form is used durin drilling or workover oDeratlons It testing cot ng Or perforating ~how formation name in dascrlblnJ;~ work performed. nstruct gna: g , ' ' ,, Number a I drill stem tests sequent al y Attach description of all cores. Work performed by Producing Section will be reported on lel~rll, sheeis until final completion. Report off c al or representat ye test on "Final" form. 1) Subm. lt "Interim" ..shee..ta when filled .o. ut.b?t not.!.ese fre.qo.e, ntly than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for worKovere and following setting o! Oll stglflg unt comp etlon. District I,County or Parish ARCO Alaska~ Inc. I Cook Inlet Field Lease or Unit Belu§a River Date and depth Complete record for each day while drilling or workover in progress as of 8:00 a.m. ROLL'N #5 12/13/88 PBD: 4629' SUPV: DL 12/14/88 PBD: 4629' SUPV: DL 12/15/88 PBD: 4629' SUPV: HE/SS 12/16/88 PBD: 4629' SUPV: HE/SS/PA 12/17/88 PBD: 4629' SUPV: HE 12/18/88 PBD: 4629' SUPV: HE 12/19/88 PBD: 4629' SUPV: HE IState The above is correct For form preparation and distribution see Procedures Manual Section 10, Drilling, Pages 86 and 87 AK 3Well no. RU 232-4 SPOT PKR W/ ATLAS WL. SET PKR. PRES. ANNULUS TO 2350 PSI TO FIVE GUNS. SIDDP 225 PSI. OPEN BY PASS. REV. CIRC TO KILL WELL. POH. LD PERF. ASS'Y. ASF. RIH W/BIT & SCRAPER. CO FILL W/3956' TO 3985'. JUNK IN HOLE. POH. REC'D GUN DEBRIS IN BOOT BASKET. RIH W/GLOBE BASKET. (PERF: (12 SPF) 3181'-3206', 3231'-3264', 3330'-3324', 3350'-3357', 3404'-3416', 3423'-3453', ,3562' 3584' 3599'-3625', 3638'-3649', 3471'-3484', 3508'-3513', ~ , 3662'-3666', 3696'-3709', 3724 -3734 ). RIH W/GLOBE BASKET. REV. CIRC. WELL. POOH. REC'D SMALL AMOUNT OF GUN DEBRIS. RIH W/RET. TOOL. REV. OUT SAND. OPEN VALVE ON RBP. CIRC. OUT GAS. RELEASE RBP. DRAGGING 10 K TO 40 K. HUNG UP @ 3969' RELEASE PULLING TOOL. POH. RIH W/ RET. TOOL, JARS & BS. WOR~ RPB FREE. POH. POOH LD RBP, RU WL & RUN 6.063" GR/JB TO 4616' WLM. RU & RUN "DB" PERM PKR & TAIL PIPE., PKR AT 3746' WLM, TBG. TAIL AT 4573' WLM. CIRC & FILTER FLUID. POOH W/3-1/2" DP. LD SETTING TOOL RU AND RUN GRAVEL PACK ASSEMBLY. FIN. RUNNING GRAVEL PACK. ASSEM. SNAP IM & OUT OF SUMP PACKER. RU DOWELL MANIFOLD. MIXED 66 BBL 8PPG SLURRY. PUMP GRAVEL PACK. CIRC & WO SLURRY TO BREAK. RETEST PACK TO 1300 PSI - OK. POOH W/DP WELL KICKED. KILL WELL, RIH W/DP. CIRC. WELL IN REV. CIRC. POSITION. POOH, WELL KICKED. RIH & CIRC THRU CHOKE ABOVE TOP PKR. POOH. FIN POOH. WELL KICKED. KILL WELL THRU CHOKE. BULL HEAD 1515 BBLS BRINE TO PERFS. POOH LD GRAVEL PACK TOOL RIH W/1-1/4" WASH PIPE & DP TO 3707'. CIRC 9.5 PPG THRU CHOKE. WELL STABLE. POOH LD 1-1/4" WASHPIPE. RIH TO 2753' W/OE DP. RU ATLAS WL TEST LUB. 1000 PSI. - OK. RUN ER/CCC/PHOTON LOG FROM '0' RING SUB TO PKR. RD WL POOH LD. FIN POOH LD DP. RUN 3-1/2"/2-3/8" COMPLETION, LAND TBG. RU WL. SET PLUG IN 'X' NIPPLE AT 2760' WLM. TEST TUBING/ANNULUS TO 2500 PSI. SET BPV. ND BOPE. NOTE: BAKER GRAVEL PACK PKR @ 2793', BAKER 'DB' PKR @ 3748', TT @ 4573' & NO SSSV. AR3B-459-2-B Number all daily well history forms consecutively IPage no. as they are prepared for each well, ~r ARL, O Oil and Gas Company Dally Well History-Final Report Inatmctleaa: Prepare end submit the "Flail I1~1~1" on fie fiflt Wednesday after allowable his ~ Mllgntd or well la Plugged, Abandoned, or ~ld. "Flail Rel~ll" ihould be submitted also when oolrsflone era lulpanold for an Indefinite or epprecllbli length of time. On worl~vlrl when in official lilt Il OM required upon completion, report completion and representative teat data In blocks provided. The "Filial Rl~ell" farm rely be u#d for repo,/lng the entire operation if spice is available. District ARCO Alaska, Inc. Field Beluga River Auth. or W.O. no. AD 6315 ICounty or Parish Cook Inlet Lease or Unit A-029656 Title Workover IAccounting cOlt center code JWell no. BRU 232-4 Operator ARCO Spudded or W.O. begun Accept Date and depth as of 8:00 a.m. A.R.Co. W.I. 0.0000 Date I 12/03/88 Complete record for each day reported ROLL'N ;/5 12/20/88 PBD: 4629' SUPV: HE Old TD Released rig Classifications (o11, gas, etc.) Producing method Potential test data Iotalnumber of wells (active or inactive) on this cst center prior to plugging and I bandonment of this well I our I Prior statue If a W,O. I 1530 hfs FINISH ND BOPE. NU WKM 3-1/8", 5000 PSI. TEST TREE & PACKOFF TO 5000 PSI - OK. PULL 2-WAY CHECK VLV & HAD PRESSURE BELOW. OPEN ANNULUS - NO FLOW. ATTEMPT TO TEST TBG. NO TEST. RU WL CHANGE OUT 'PX' PLUG. TEST TBG 2500 PSI, DISPLACE TO DIESEL. PULL CV. RUN DV IN ELM @ 2700' WLM. PULL 'PX' PLUG. CLEAN PITS, SECURE WELL. RR 2400 HRS, 12-19-88. INew TO Date IPB Depth Kind of rig Type completion (single, dual, etc.) · ]Official resewolr name(s) Well no. Date Reservoir Producing Interval Oil or gas Test time Production OII on test Gal per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected For form preparation and distribution. · / I son Procedures Manual, Section 10. Drilling, Pages 86 and 87. AR3B-459-3-C Number ltl dally well hlsto~/forma conlecutlvely is they ere prepared for each well. jPsge no. DMdon M AIl~tk:R Ichf IMdCom pan y ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMI'I'T~ #284 T~. John F. Boyle COMPANY: AOC~C DATE: Jan. 13, 1989 FROM: Tom Wellman COMPANY: ARCO Alaska, Inc WELL NAME:Listed below Transmitted herewith are the following Blue Sepia Sepia Line Folded Rolled Mylar Tape Photon Log BRU 232-4 1 1 Receipt Acknowledgemem: Return reciept to ARCO ALASKA, Inc. ATFN: Judy Boegler ATO 1390A Post Office Box 100360 Anchorage, AK 99510- ARCO ALASKA INC. Cook Inlet/New Ventures Engineering TRANSMrYrAL #278 TO: Commissioner COMPANY: AOGcc DATE: Dec.23, 1988 FROM: Tom Wellman COMPANY: ARCO Alaska, lnc WELL NAME:Listed below Transmitted herewith are the following I Blue Sepia Sepia Line Folded Rolled Mylar Tape BRU 224-13 ~ Acoustic CBL 5" 1 1 · PDK-100GRCCL 5" 1 1 · Collar Lo~ 5" 1 1 · Gamma Ray 5,' 1 1 BRU 232-4 ,' Acoustic CBL VDL/Si~a/GR 5" 1 1 SCU 41A-9 · Production Lo~ 5" 1 1 Receipt Acknowledgement: ;as .Co. .Corn ;; o. Remm r~iept to ~CO ~AS~, ~c. '~ ~<~~";'~': A~: Judy B~ ATO 1390A Post ~fice Box 1003~ ~chorage, ~ 99510- STATE OF ALASKJ~ ~"="~ A L,-,,.,KA OIL AND GAS CONSERVATION COM M I~,.,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ . Operation shutdown __ Re-enter suspended well ~ Alter casing __ Repair well .~ Pluggi~ng ~ Time extension ~ Stimulate ~ Change approved program __ Pull tubing -X- Variance __ ~,-Perforate -Z-' Other 2. Name of Operator ARCO Alaska. Inc 3. Address P. O. Box 100360~, Anchorages, AK 99510t0360 4. Location of well at surface A1990.' F.NL~ 1987'. FEL, Sec. 4, T12N, R10W, SM t top eT productive interval 1990' FNL, 1987' FEL, Sec. 4, T12N, R10W, SM At effective depth 1990' FNL, 1987' FEL, Sec. 4, T12N, R10W, SM At total depth 1990' FNL, 1987' FEL, Sec. 4, T12N, R10W, SM i5. Type of Well: ,~, Development ~__ . Exploratory __ Stratigraphic ~ Service __ 6. Datum elevation (DF or KB) RKB 10/+' 7. Unit or Property name Beluga River Unit 8. Well number BRU 232-4 9. Permit number N/A 10. APl number 50-- N/A 11. Field/Pool Beluga River 12. Present well condition summary Total depth: measured true vertical 5300 ' M D feet Plugs (measured) 4629 ' - 4675 ' 5300 ' TVD feet Effective depth: measured true vertical Casing Length Structural Conductor 29 ' 302' Surface 2223' Intermediate Production 4 6 59 ' Liner Perforation depth: measured true vertical 4629' MD feet Junk(measured) None 4629 'TVD feet Size Cemented Measured depth CEIVED 302 'MD 3988 224O,MD 7" 725 sx ~laska 0ii & Gas Cons. C0m~' M D Anchorage ~o~8~-~o58. ~ ~22o~-~227~ 4~3~-~5o~ ~89~-~5o3~ ~538~-~5~5~ 36" I 6" I 0.3/4" Same as Above ~bing(size. grade, and measureddepth) 2-3/8", N-80, Circulating String w/tail ~ 1993' 2-3/8" N-80 tbg w/tail ~ 4531' PackersandSSSV(typeandmeasuredde~h) Brown 'HS-16-1' pkr @ 3943' Description summary of proposal __ 13. Attachments Detailed operations program __ BOP sketch .X- ~uevedicaldepth 29'TVD 302'TVD 2240'TVD 4675'TVD 14. Estimated date for commencing operation November 1~ 1988 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas _~ ~spended __ Date SUBMIT IN TRIPLICATE Service 17. I hereby certify that the foregoing is true and correct to the best of m, / knowledge. Signed 4, (~/)f~AA ~]£/,~k ,, Title As sec i ate E nq i nee r Date ~-- Conditions pproval: Notify COmmission so representative may witness ( J 6 ) S A 3 / 0043 Approval No. Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- '¢ &pproved Copy Returned - LONNIE C. SMITH Approved by order of the Commissioner Commissioner Form 10-403 Rev 06/15/88 Sul~scque~t Work Reporte(~ or~ feet General Workover Procedure BRU 232-4 Single Stage Gravel Pack Prior to MIRU 1. RU slickline. Set tubing plugs in D nipple at 4006'. Open sliding sleeve at 3896'. RD slickline. 2. Circulate 9.0 ppg-NaC1 brine down long string, ~i~ I77~ thru heater string, then 2nd thru annulus. 3.Set BPV in both strings. L ~ 1 ~::: 1988 Rig Related Work S~ 1. MIRU k~aska0ii& GasCons. Commission 2. ND tree. NU BOPE's and test. Pull BPV. Anchorage 3. RU slickline. Pull tubing plug from D nipple. RD slickline. 4. Circulate well to be sure it is dead. 5. Install 2-3/8" BOP Rams and pull heater string. Pull long string by rotating off cc safety joint. 6. PU fishing tools and retrieve Brown packer. 7. PU bit and casing scrapers. Clean out to PBTD at 4629'. Circulate well and POOH. . 8. TIH with RBP and set at 3930'±. Test 9-5/8" casing to 2000 psi for 30 minutes. 9. ND BOPE and tubing spool. NU new tubing spool and test. 10. TIH with retrieving tool and POOH with RBP. 11. RU E-line run CET. Squeeze as required. 12. RU electric line. TIH with sump packer and set below bottom perforation. 13. TIH with TCP guns and reperforate designa[cd interval. Flow well for clean-up, kill well, and filter brine. POOH. 14. Pre-pack perforations and cleanout to sump packer. 15. PU gravel pack assembly, TIH, set gravel pack packer and proceed with circulating pack. POOH with x-over tool and wash pipe. 16. RU and RIH with 2-7/8" production tubing and equipment. Space out as required and land tubing. 17. RU and RIH with heater string and land. 18. Install BPV's in all strings. ND BOPE. NU tree and test. Remove BPV's. 19. Displace well with diesel. 20. Install BPV's. Release rig. 21. Release well to production. P : ll/-OO p s ; ,4'r ! ss/s2 ih 11" 00 P lB PTA K ANNULAR PREVENTER 8 PIPE RAMS 7 BLIND RAMS 6 3 1. 16" CASING 2. 10-3/4" CASING HEAD 16-3/4" - 3000 PSI FLANGE 3. 16-3/4" - 3000 PSI X 11" - 3000 PSI CASING HEAD 4. 11" - 3000 PSI X 7-1/16" - 5000 PSI TUBING HEAD 5. 7-1/16" - 5000 PSI X 11" - 5000 PSI CROSS-OVER SPOOL 6. 11" - 5000 PSI BLIND RAMS 7. 11"- 5000 PSI PIPE RAMS 8. 11" - 5000 PSI ANNULAR BRU 232-4 ACCUMULATOR CAPACITY TEST w,...~o~,c ~,~. ~. ~ssu.~ ~.~ ~cc~~o, ,.~ssu,~ ,s ~ooo ,s, w,~. 15~ PSI ~~STR~M OF ~E REGU~TOR. 3. ~ERVE ~ME, ~EN CLOSE ~ UN~S SIMULT~E~SLY AND RECORD ~E ~ME ~D PRE. RE R~NNING A~ER ALL UNITS ARE CLUED Wl~ CH~GI~ ~MP O~. ,..~CO.O ~ ~,*~,~.~. ~*CC~~ ~OW~, ~,.,~ ,S ~ S~CO. OS C~OS,.~ ~,.~*.. ,~00,S,.~U*,.,,~ ~~RE. R E C E IV [ D BOP STACK TE~T b I::. r' I ,~': 1988 Commissior! 1. FILL BOP STACK AND MANIFOLD WI'I~I~.& Cons. ~. CHECK TH^T ~ .a.O-~OWN SC.EWS A.E ~.'~E~P~CT~D. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4.TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6.OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7.INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 5000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 5000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. DM 08/31/88 STATE oF ALASKA DEPARTHENT OF NATURAL RESOURCES Division of Oil and Gas Conservation TO: F-- FROM: HEMO TO FILES Harry ~. Kugler Petroleum Geologi st DATE : June 13, 1977 SUBJECT: Be 1 uga Ri ver F i e I d Dave Courtis, Union 0il Company of California, called this date to report that there were no mud logs in the State files of the following wells: Socal BRU 212-25 Completed in 1962 Socal BRU 233-27 Completed in 1963 Socal BRU 212-2/.I Completed in 1973 Socal BRU 22Z~-13 Completed in 197/~ He stated that he believed our regulations are such that we should request Socal (Chevron) submit these logs if they were run. I reported, after consultation with the Director and staff memberst that our interpretation of the regulations were not -the same and we would not require the mud logs. Upon hearing this, he stated he would turn the matter over to Unionls land department for their interpretation and the land department would be in touch with us. Standard Oil Co. of California Beluga River Unit No. 232-4 Permit No. 37-62 Issued: 12-12-62 Loc: 1990' FNL & 1987'~ FEL Sec. 4, T12N-RIOW, SB&M Elev: 104' K.B.' 89' Grd. Contr: Coastal Drilling Co. Spud: 1-4-63 Comp~ GSI 2-2-63' T.D. 5,300' I.P. 7,750-MCF, 20/64" Bean, T.P. 1645 psi. Csg: 36" C 29' 16" C 302' w/600 sx 10 3/4" C 2240' w/1200 sx 7" C 4675' w/525 sx @ shoe & 200 sx thru DVC 2002' Plugs: 4675'-4629' ' Perf: 4 h/ft. 4048'-58'; 4220'-27'; 4443'-50'; 4489'-4503'; 4538'-45' ' ~' UNITED C 0 NF I g E N T I AL U 'l '......... ~m DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS ..... _A!a_sk_a. .......... Coun~g _~.._c_..09k____I_n!_.e~ ............... t~eld Beluga River Field 7'/~e followin~ is a correc* report of opera~on~ a~d produc.',';on finclu, din~ drfH. in.~ and produci?t~ for tt~,~ mo, t,..~ of ........ F.e.b_..~.. Ar'/ ................. /,9_63 ....... .B.e..1._.uga River_ .g_n_i..~ ....................................... ........................................... Anehqr___age,....Ala~ka ........ $i~ned._ ~ "' C*.~; L'2q'A~TOR I 12NJlOW~ i BE AR UNIT 32-4 (3~ iRates ~ Fl.c~ tested for pro, duction., f , ~ean S ze R~te 2~/64" 7750 I~F/D 2}-/6h" 62~ ~6F~ 2( 64" 45~ MCF~ 16/64" 2460 ~[CF~ s~t in ~ressure l' Ri~ released Yebrm ca Tbg,, Pressure 164! 173( ~75# psi.. ; I ry 2, 19!3. o J.S.G.S. -M. S. So~ster (2 3tare - T~ R. Marshall [ tle~ - Pr~ducing L~td ~ ~lors¢ion , psi psi psi psi Ro R. Robinson NoT~.--There were ....................................... runs or sales of oil; ............................................... M cu. ft. of gms sold; ............................................. mss or sale. s of gasoline during the nton%h. (Wrke "no" where applicable.) NOTIil. Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6~h of the succeeding month, unless otherwise directed by ~he supervi.~or. ~ laor~x 9-329 UNITED S'I"ATE$ DEPART?d£NT OF THE INTERIOR GEOLOGICAL SURVEY ,..,,,,: - .Beluga River . ES EE'S MONTHLY OPERATIONS Alaska (:'o t,/,. C.'! -- - ..... *~ .... ' January ",63 ,&~r,.,.,, P~ O. Box 7.-839 .................. ~nehorage~ ~laska ........ BRoadway. 7-'62Ol_.. . q'wP, I{A:','(.~I:: ' BAP, g~L,:{ 0~' OIL ! ~[*,.t;::* I (il~ thou~a:: ' ) I { { ].~- ..... ~ h I [ I Spudded January 4,;1963. F',' .~',., Beluga River r~;d;~,"~io/~ ~:,.~'[',t,'~,;'/ ,:ri;h/;,'; a.,td /.,r:.;<:.,~.';.'., Beluga River Unit . STJ~NDARD OIL CO. OF CALIFORNIA . ,/. , .,-w~t,.ei~.~,e~.-at..lon~, .:[nc, ../::,,,, '.,~: ,. Di,trlct Superintendent-Alaska 12N lOW I Drilled 30~' and cemented 16" casing at 302' with 600 sacks cement. I~stalled BOPE. Drilled 14 3/4" hole to Ran logs. Ran and cemented 10 3/%" casing at 22k0" with 1200 sacks cement around shoe and 1OO sacks through 1," pipe at i00'. ! Reinstalled BOPE. Dr~!led 9 5/8" hole to Ban~: logs. ~n ~ ~1, 298~' - 3o2~'. Drilled %o 5000'. ~n~ logs. Dril~ to 5~O' T.D. ~n logs. Cemented cas~ng at 46'f5' wi~h DV at 2002'. Drilled out DV and drilled ee~nt to 462R' ~ NCL and C~. Perforated with 40 ~in. flow ~est. Flo~d d~ ~s. P~szures: IH~ IS1.21~5, ~ 1310, FP 1610, ~I 2065, and ~H 2%~ p~l. Per~o~t~d with 4 ~ ~" ~les per foot ~489'. - 4443'- ~450', ~220' - 4~27', and ~' - ~O5~' . ~.nded 2 3/8" tmbl~ at 4531'~ and 2 3/8" ~eater s~rlng at 1)~2'. Installed and tested ~s ~ree. Disp~ced mud with oil. Flowed well clean. cc:~ U.$.G.S. -~. ~. 8o~te~ (~) Richfield - C. W. ~Perry R. R. RiOter Shell- O. L. ~e At,n: R. R. ~bison Files: Pr~ucing ' I ......................................... t RECEIVED FEB NOTE, There v/'erc ...................................... l'tltt,~ or sales cu. ft. of gas sold; ........................................ runs or sales of ~_'.asMine during thc mon(h. (Write "no" wl.,.,:e applical~le.) NoTs.---Report duplicate with lhe supervisor by the 6th of the .~uceeeding month, unless uti:orwise d{~-,;(.ted by the sttl)rrvisor ' Form (J~uary 1950) (Feb. 1961) ($UBM~ IN TRIPLICATE) UNITED ~b~I'ATE5 ,- DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS SUBSEQUENT REPORT OF WATER SHUT-OFF ..................... ~ _ SUBSEQUENT REPORT OF SHOOTING OR ACIDIZING ............. :_ SUBS~QCJENT REPORT OF ALTERING CASING .................... SUBSEQUENT REPORT OF E-DRILLING OR REPAIR ............... SUBSEQUENT REi~RT OF ABANDONMENT ................... SUPPLEMENTARY WELL HISTORY (INDICATE AINT)VE BY CHECK MARK NATURE OF REPORT, NOTICE. OR OTHi~ DATA) December' -_? ......................19_~_ Well No~_~t:~32:'_~__ is located L9_9(~ ft. from ~ll. lineand 1~7 ft. from I1~ line of sec .... S .B.M. (M~ldl~n) Alaska (State or Territory) The elevation of the derrick flo~,, above sea level is :-~>~ ft. DETAILS OF WORK -.w ~Jflt., and mil other im~ttant pro~ w~k) 1. Drill to 3~' cedar ih" con~]uctor and install C~ss 1ii ~PE , 2. Drill to 2~5'~, ~ togs and cement iC 3/4" easing at 2~b5'! (cedar ~o surface 3. I~ll C~ss ~ Blo~u~ P~-.:n'ticn Equlp~n% and test before drilli~ out. -' 4. Drill ~ ~%' and rain Logs. ~. Ce~ 7" on bottom. 6. Ins%all Class IV Blc. wou~ P~vent~on Equip~n%. -~. ~s~blish WSO's a~ perforce att:~ctive intervals aad co~lete ~8 a ~s well. that thi. plan cd work must rec~ve approval In wrltlnI b! the Geolowtc.i ~urv®¥ before opmretJIOl~ may be commenced. Address .: .... _P__.____O__._____~_._x__ 7=839 ....................... APPLICATION TO DRILL:~_ ~. DEEPEN U] PLUG BACK DATE Address -~" - · ' -':. ...... -~ - ~ - ~ CitY: ' State -"-' .... · -~:-; :' ~SCR~PTION "OF ~rELL :AND LEASE Name of lease [ Well .qumber [ Elevation (ground) AVell location (~ive fQota~e from section lines) Section~townshiP~r~nKe or block & ~urvey Field & reser~oir.-(If~ql.dcat,'sp:state)~- ~. : _~L~-. ~- -. ._ .[:Count~ ', . _ Distance, in miles, and direction from nearest town or post office Nearest distance from proposed location ~to property or lease line: feet Proposed depth: Rotary or cable tools Distance from proposed location to nearest drilling, completed or applied--for well on the same lease: feet Approx. date work will stare Number of wells on lease, including this well, completed in or drilling to this r~.qervoir: 1 If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of. bond Remarks: (If this is an application to deepen or plug back, bt. icily describe Work to be done, giving present producing zone and expected new producing zone) CERTIFICATE: I, the undersigned, state that I am th '..e~.~.~/~~- of the (company), and that I am authorized by said company to make this report; and that this report was pre. pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of my knowledge. Permit Number:. Approval Date: ~ ~'~g ~ Approved By: ~, ~!~~ Notice: Before sending in this form be sure ,that you have given all informatio~ requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form 0,,,.. ,~:~ Signed 'C. Y_ C!-.;f~ffTFRTO~ Signature . C?v' ~ Alaska Oil and Gas Conservation Commission Application to Dr/l/, Deepen or Plug Back Form No. P-1 Authorized by Order No, 1 Effective October 1, 1958 TRACE DATA STRINGS ~I.~ I ~tSP 555.66 6872.69 g:~. 59 - 199 .25 '~..23~38 29 SLRE[ S 212822 )~ '1 ZLDDZLZ ~SP ~55.69 68~2.~8 g..Sg -999.~ 25~ :2gg.g. :g~ 26 SLRLX S 21282~gg '~ ,t SFLUD:[ L1 MSP .355 ~ BB 999~ 46 ]. N M', 68 6 go5 5.73828 2! SLNL[S 212822t18 ) ~7' ]. NCNL CNL~: HSP 355 ~ ~ 68 ~2. gg ~.5 g "999~ i9 3516.~ ~ 26 2128 ~ t CAL; 6H C~ MSP 22 27 I 28 I 'M'NOR PR X]. MSP 355.98 6872.66 NUMBER O.F HEADER AND DATA RECORDS IN DATA FILE = 369 * * PL 7~ 2.9 SLRLIS 21282296 -999, 5fJ6 53o,~79 28 SLML! S 2128 226t~ CURR£NT NUMBER OF ACTIVE TASKS IS :'"** PROCEDUR~ MSPJOB KCLI:i ¥1'U OCT 2 5 !982 43 A~ka 0il & Gas Cons. Commh~dofl Anchorage. .*** PSP dgB BECWTSC3 HA~.ING EXTENDED TASK NAME H3/82.2gi~/.22'2L~:q~ HAS 82 DATA STRINGS LISTED BELOW TRACE DATA STRINGS '~'* - -GEN~~~* NAME .... ~* -TYPE~'ACE- .......... -~, TOP * BOTTOM · CURVE-I~"URMASAMPLE * ~ MINI~UH~N , HAXIHUH *~ .......... RECORDsNOg ........ OF '~, ....... PR~GRA~FROM ** · {IMNAHE)* TRACE*CODE * * *INCREMENT* ~ * * * * · , . . . . , . · , . . . . . . , . . . . . . . . . , . . , . , . . m* * , · . . . , * . . · . , , , , . , . . . . . i T~-NSZSN1 MSP 5778 ~ ~ 5~ E.S~ 111~.~ ~828.~ 2 SL~LIS i MARKISNI MSP 5778,~ S~,5~ ~.5~ 34.E2~9 53,1875 2 SLMLIS 222822~ I CALIISN1 MSP 5778,E~ 5~,5~ ~,5~ ,~ [, 12,25~ 2 SLRLIS 222822~ I DTISN1 M.SP 5778,~E $~,SE ~,5~ 86,~75~ 139,375 I SPHIISN1 ~SP 5778,~ 5~B,5~ ~,Se ,18~'9~1 ,521912 .. . :~ .......................... T ................. ~'I-~NY ................................... M~'~ .............E7'78' ;'9'~ ~"~ ~'"~'; 5'.~ g; 5e .......... ~"7~ ~"~ ...................58~";~"~B I AMPLISNi MSP S778,9.? S~,5e ~,5~ 2,75976 181,'7~ 1 CBLISN1 MSP 5778.Z~ 6~q~.5~ ~.5~ .78q~8 47.5313 2 1 SRA'TISN1 MSF 5778..9e G2~B.5~ ~.5~ .517578E-~1 2.599G1 2 1 CSISN2 MSP ~884.B~ 6~5.9~ 9,.5~ 69.~'g6~ 3779.g~ 7 1 MARKISN2 MSP 388q.~ 6~35.~ ~.5~ .~ , ~B.~B~ 7 ! CALII.SN2 MSP 388~.Z~ 5~35o!~ ~.5~ .? 1 SPHIISN2 MSP 3884.~ 5~.35,~ ~,5~ -,3G~769 1,.,'lIB ~52 1 1ENSMPT3 MSP 5278. 1 CS~PT3 MSP 5378. 1 MARKMPT3 MSP 5~78.¢¢~ i MNO3MPT3 NSF 5378, ~.9 5576,~e ¢,5~ 2,51758 53,~9.38 I MINVMPT.~ M.SP 53'78. E:~ 55'7G,~ ~,5~ :3. ~ 25.39 4,5 2 SLMLIS 222822.a,~ 2 SLMLIS 222822~ 7 SLMLIS 222822;~:~ ~ 0 '~ 3~ o8'75~ "?q.5625 73.375~ 12,25~ q780,~ 29AS.Z~ ~6..t25~ 7 SLMLIS 2228220~ 7 SLMLIS 222822~ 7 SLMLIS 222822~ 2 SLMLIS 222822:¢~ 2 SLMLIS 22.2822~8 2 .SLMLIS 222822~ '53 64, 0o5~ . 1132 81 5 o li~ 156 2 1925 .~ ~728.~ 1122 .~ 3688.~Z 7 -32 L25 ,~ 7 -29 ,~. 12o25~ 7 -22 ~25 23'7o75~ ? 181. 125 1'?~9.~ 2~1.~0f 2q68.~ 181.125 2~72.~ 7 · 4225-~2 2.871~9 7 -1 269.75~ NUMBER OF HEADER AND DATA RECOROS IN .DATA FILE - 3:69 '*** PLOT NUMBER Al TERMINATION OF THIS UCB IS ~ *** SLMLIS SLMLIS SL~LIS SLMLIS SLMLIS SLMIlS SLMLIS SL~LI$ SLHLIS S£MLI$ SLMLIS SLMLIS SLMLIS SLMLIS 2228220~ 222822~ 222822~ 222822~8 222822~ 222822~2 22282"2'~ ,222822~ 222822~ 222822~ ~ 222822~ 222822~e 222822~ 222822~ SEM£IS .......... 22282'2B~ SLMLIS 222822~e SLMLIS 222822B~ SL~LIS 222822aa S'LM£'I'S' 222822~ SLMLIS 222822~ SLMLIS 222822~ SLMLIS 222822~ SLI'q:'IS ..... SLMLIS 222822a~ SLMLIS 222822~ SLMLIS 222822~¢ ***** MSP d~'B:':BECWTSC3 HAVING TASK NAME C8F382~2~O222~qq *** PROGRAM MSPOFF COMPLETED WITH A CODE OF ? **** ~BEEN DELE:TED 32 :; 5 AT. 2Z~23.~5 USING 52BK?: I52K BYTES MEMORY · ~~~ .................. ~' ........ TR~CE ........ * CURVE INFORMATION * ..... NO'~ ' OF * FROM * CR'E'AT'IO"N~ · SEN * NAME * TYPE · (IWNAME)* TRACE*CODE * * *INCREMENT- . , , , , , , , , , , , , , , , , ** , , , , *** , , ** ** , , ** , , , , ** ** , * , * * * * * * * * * * * * * * ...................... 1- ............... TT'~-E'IS-Ni NSF 579~* ~ 5~42,5'~ ~,59' 2'7 ~] ;"~'~ 3 5'~5~; ~8 2 SLML IS 223822~8 I TENSISNI MSP 5796.¢4 ,58¢2.59 2.5~ I;?~.~Z ~1~'~.8~ 2 SLMLIS 22~8228~ '1 CSISN1 MSP 5'796. ~Z 5~42.5g I NARK ISNt MSF E796. ~ C 6F~2.5¢ ¢.59 7..5~125 ~.9375 2 SLHLIS 223822~J I ILMISNZ MSP '5796.~ ~42.5¢ ~.5~ 5.~7~ ~2.5~Z~ 2 SLMLIS 22~822¢8 I SFLUI~N1 MSP 1 ILDISNi MSP I TINEISN2 MSF ;g21.~; ~2.5~ ~.5~ 25.~8~ tq2~.~ 7 SLMLIS 22~822aa i MARKISN2 MSP :39~1.5~ 68~2.5¢ ¢.5¢ 1 SPISN2 MSP 3921.5~ 6¢~2..5,8 ~.5¢' -~5.~, ~8~ .~ 7 SL~LIS 22~822~'~ I IL~ISN2 MSP 3921.5¢ ~.~ ~ 2,.5¢ :9.5¢ .61~ ,¢2~ 2~¢.~8 7 SLHLIS 223822~ '7 7 SL~L[S 22~822 ~';~ 13'7 28i)8o0e .258 1793..~0 129 2ii~8o~ I SFLUISN2 MSP 39~1.59 G2~2o5~ ~.50 .14 I CILDISN2 ~SP 3521.5~ S~2.5~ ~.5~ -312 1 ILDISN2 MSP 3921,.~ Si~2°5~ ~o~ .:~-, :3 1 BSISN3 MSP 5797 .,~ ~M~3.MM M 5¢) 12 12.25i]t~ .I RHO~ISN3 MSF 579'7.5.~ 67~3. g~ 8 ,,, 5 l~ 1.4 ]527 2 oz~OM39 1 ORHOISN3 MSP 5'797.5:9 5;ii~ 83.. ~ ~ ~,.5¢ -.5S t, 54E-~ i · 16'7969 . 1 GRISN3 MSP ~79'7.. 58 6.Z~3.8~ 0 .'5~ ~7. ~ 86.3758 1 R. HGXISN5 MSF 5797..5~ 6~q3.~ 0.59 2.5 ~t8 8..~5.313 I TIMEISN4 MSP 3789.¢g 5,¢37.~ ~.5~ 812 ~¢ 28~.~ ;,.¢.~ .1 RHOSISN~ MSP .~789.~ 5¢5'7..8~ ~.5~ 1.21289 2.68.359 1 ORHOISN~ MSF 3'789..~ G~3'7°~ ~.5~ -1.28711 .158672 42 ( 4 .% 4? ( ? SLMLIS ~2~822~!~ ~., ( 7 SLMLIS 2'238.22 ¢.¢ r,5 ' '1 SLMLIS 223822~¢ ,:?!,, 7 SLMLIS 22 3822~:~ ~::~ ( 6 SLMLIS 223822~ , 6~ 6 $ L M L I S 2 2 ~ 8 2 2 ~ :e ~.~.~ G SLM~LIS 22~8228¢ i G SLMLIS 22~822~¢ ~ 6 SLMLIS 223822~ ~..'=~ ~ · 1'79687 8.5B .148137 ~.5~ -~I'~'z.25~ ?.5~ '557 -I~ER-~I~FDE~-~ANU~'DATA'"'RE£OROS IN UATA FILE= 291 *** PROGRAM SLMLIX COMPLETED WITH A CODE OF ~ 3 '-O'N' SY~TER C~3'3 AT 22:3'6':2&" USING 52~K/ 892K BYTES MERORY *** 2~ 32 3'3 39